The URL can be used to link to this page

Home My WebLink About168-107 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday,October 23,2017 TO: Jim Regg j P.I.Supervisor . 7C1 (t)P'� I 1-7 SUBJECT: Mechanical Integrity Tests HILCORP ALASKA LLC C24-23 FROM: Matt Herrera MGS C24-23 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry JDl� NON-CONFIDENTIAL Comm Well Name MGS C24-23API Well Number 50-733-20145-01-00 Inspector Name: Matt Herrera Permit Number: 168-107-0 Inspection Date: 10/20/2017 - Insp Num: mitMFH171023090306 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well C24-23 ' Type Inj W TVD 7659 ' Tubing 3575 ' 3575 3575 " 3575 " PTD—1 1681070 Type Test' SPT Test psi 1915 IA 344 1958 ' 1952 1950 BBL Pumped: 0.4 BBL Returned: 0.4 - OA 50 ' 50 50 50 Interval 4YRTST P/F P ✓ Notes: SCANNED !' 6 2018 Monday,October 23,2017 Page 1 of 1 1111■111■111.6 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday,October 01,2013 TO: Jim Regg P.I.Supervisor (\- .4/ 14111 3 SUBJECT: Mechanical Integrity Tests XTO ENERGY INC C24-23 FROM: Jeff Jones MGS C24-23 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name MGS C24-23 API Well Number 50-733-20145-01-00 Inspector Name: JeffJmes Permit Number: 168-107-0 Inspection Date: 9/16/2013 Insp Num: mit.11130924182841 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well• C24-23 - 'Type Inj w-TVD ! 7659 i IA 20 I 2100 — 2100 1 2100 - I PTDj -- 1 - I 1681070 Type Test SPT Test psi 1915 1 OA 50 50 50 - 50 • I Interval 11141TAL • P/F P 'Tubing" 3500 . 3500 I 3500 . 3500 Notes: Initial MIT. 1 well inspected,no exceptions noted. SCOW 4 'J Tuesday,October 01,2013 Page 1 of 1 Brooks, Phoebe L (DOA) MO I be 1070 From: Phillips, Barney[Barney_Phillips @xtoenergy.com] Sent: Friday, September 27, 2013 3:01 PM To: Brooks, Phoebe L (DOA) Subject: RE: MGS -XTO Energy- MIT Reports Attachments: A33-14 WIW Current WBD 6-25-13.docx; C24-23 WIW Current WBD 5-20-13.docx Here they are Phoebe. If you need any further information, please let me know. Barney From: Brooks, Phoebe L(DOA) [mailto:phoebe.brooks@alaska.gov] Sent: Friday, September 27, 2013 7:39 AM To: Phillips, Barney Subject: RE: MGS -XTO Energy - MIT Reports Thank you. Phoebe Brooks Statistical Technician II SCANNED DE(P, 0 y 201 Alaska Oil and Gas Conservation Commission Phone: 907-793-1242 Fax: 907-276-7542 From: Phillips, Barney [mailto:Barney PhillipsCa�xtoenergy.com] Sent: Thursday, September 26, 2013 4:27 PM To: Brooks, Phoebe L (DOA) Subject: RE: MGS - XTO Energy - MIT Reports Hi Phoebe, The schematics I have here on the platform are labeled "Proposed" in the header and I do not have the program to change it. Our engineer is going to send me the updated copies tomorrow and I will get those to you as soon as I get them. Thanks! Barney From: Brooks, Phoebe L(DOA) [mailto:phoebe.brooks@alaska.gov] Sent: Wednesday, September 25, 2013 1:50 PM To: Phillips, Barney Subject: RE: MGS - XTO Energy - MIT Reports Thank you. Phoebe Brooks Statistical Technician II Alaska Oil and Gas Conservation Commission Phone: 907-793-1242 Fax: 907-276-7542 1 . • AAA 5-20-13 fto GY Current Completion KB: 35' MGS C24-23 WIW Water Depth: 73' MSL Cook Inlet, Alaska v Leg 4, Conductor 32 rAt Upper Completion API No.: 50-733-20145 4' Pup Jt, 2-7/8"6.5# 1% Cr 8rd @ 293' Spud: 11-24-68 2-7/8"X Nipple(2.313" ID) 9Cr @ 297' Sidetracked from C11-26 4' Pup Jt, 2-7/8"6.5# 1% Cr 8rd @ 298' 250 jts 2-7/8"6.5#L80+1%Cr 8RD EUE 24" Conductor Casing @ 370' 4' Halliburton Sliding Sleeve @ 7742' 4' Pup Jt, 2-7/8"6.5# 1% Cr 8rd @ 7747' 2-7/8"X Nipple (2.313" ID) 9Cr @ 7751' 4' Pup Jt, 2-7/8"6.5# 1% Cr 8rd @ 7752' 40.5#, J55. 1 jt 2-7/8" 6.5#L80+1% Cr 8RD EUE Surf Csg: 10 3/4", Set @ 1830', Cmt 40 1300 sx. 7" Baker FH Retrievable Packer @ 7793' 4' Pup Jt 2-7/8 6.5#L-80 8rd @ 7800 2 jts 2-7/8"6.5# L80+1% Cr 8RD EUE 6' Pup Jt, 2-7/8"6.5# 1% Cr 8rd @ 7863' 2-7/8"XN Nipple (2.205" ID) 9Cr @ 7870' 6' Pup Jt, 2-7/8"6.5# 1% Cr 8rd @ 7871' 3.5"x 2-7/8"TIW Overshot @ 7878' Lower Completion Installed 8-4-72 3-'h"Tbg stub top @ 8078' Otis 'X' Nipple (2.75" ID) @ 8981' Otis'Q' Nipple (2.635" ID) @ 8992' V o 1/49 104 11 rill pr ra ►.t ►�� 7"TIW HB-BP Permanent Packer.Failed 01 during workover,cut pipe and run new OM 11=04, packer PO 3.5"x 2-7/8"TIW overshot @ 7878' Guiberson RH-1 pkr @ 8081' GN-GO: 8108'-8140' KBG Mandrel#1 @ 8233' Otis'XO'SS @ 8268'(closed) Collapsed Csg 8120-30'. Repaired w/csg roller in 1972 before running isolation packers. Guiberson RH-1 pkr @ 8272' ►/ 19 g p 0 0=_—_ GR-GS: 8413'-8466' _ HC-HD: 8702'-8709' KBG Mandrel#2 @ 8759'(dummy) HC-HD: 8720'-8758' Otis'XO'SS @ 8795'(Open) /140 mlimmim HD-HE: 8766'-8775' Guiberson RH-1 pkr @ 8799' �■∎�� KBG Mandrel#3 @ 8857'(dummy) HE-HF: 8824'-8865' Otis'XO'SS @ 8892'(Open) .�� Tbg Punch @ 8910-20' Guiberson RH-1 pkr @ 8896' HI-HK: 8928'-8942' _--gar,...._ KBG Mandrel#4 @ 8932'(dummy)pli- Otis'XO'SS @ 8967'(closed) HI-HK: 8955'-8967' Guiberson RH-1 pkr @ 8970' / W A Longstring: 7" N80 Set @ 9530'. HK-HN: 8985'-9110' 26#BTC-Modified: surf—634' V HN-HR: 9128'-9185' 26#BTC: 634' 8070' &29#BTC: HN-HR: 9198'-9278' 8070'- 9530'. r �/1 HR HZ: 9312'-9333' ACmt w/960 sx. HR-HZ: 9355'-9440' TD: 9555 1Ardt STATE OF ALASKA ALA.OIL AND GAS CONSERVATION COMMON REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon U Repair Well U Plug Perforations U Perforate U Other U Eliminate tbg x csg Performed: Alter Casing a Pull Tubing 0 Stimulate-Frac p 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 ❑ Exploratory ❑ 168-107 3.Address: 9127 S Jamaica St,Englewood,CO 80112 Stratigraphic❑ Service isi 6.API Number: 50-733-20145-01-00 • 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 0018756 • Middle Ground Shoal C24-23 • l- 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): MGS E, F, G Oil Pool • Al_'Ci 2 9 2013 11.Present Well Condition Summary: ;' v,, Total Depth measured 9,555 feet ' Plugs measured NA feet true vertical 8,991 feet Junk measured 8,081 feet Effective Depth measured 9,441 feet Packer measured 7,793 feet true vertical 8,896 feet true vertical 7,282 feet Casing Length Size MD ND Burst Collapse Structural Conductor Surface 1830' 10-3/4" 1830' 1812' 3130 psi 1580 psi Intermediate Production 9530' 7" 9530' 9383' 7240 psi 5410 psi Liner Perforation depth Measured depth 8413-9440 feet , ); •1J t`' True Vertical depth 7897-8895 feet Tubing(size,grade,measured and true vertical depth) 2-7/8",6.5#,L-80,EUE,8rd;EOT @ 7,878'MD,7,368'ND Packers and SSSV(type,measured and true vertical depth) 7"Baker FH Retreivable Pkr©7,793'MD,7,282'ND;'X'Nipple @ 297'MD,297'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 261 175 psi 3475 psi Subsequent to operation: N/A N/A 250 175 psi 3475 psi 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development Service in ' Stratigraphic ❑ Daily Report of Well Operations yes 16.Well Status after work: Oil ❑ Gas ❑ WDSPL❑ GSTOR ❑ WINJ 0 • WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 312-259 Contact Sandra Haggard Email Sandra Haggard(a�xtoenergy.com Printed Name Title Regulatory Analyst ///'- Signature Phone 3°a.1 397 37J Date flit//a Form 10-404 Revised 10/2012 5 s ��10 01 Ail 3 MS1 OStP - 4 . //rte • K (TO V AUG 29 2013 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 and repair tubing—casing pressure communication Middle Ground Shoal#C24-23 Water Injection Well Middle Ground Shoal Field E, F&G Oil Pool Cook Inlet,Alaska API 50-733-20145-01-00 XTO Energy hereby submits the report of sundry well operations to pull the tubing, repair well, perforate and run newer string. 1"13 BAs. ' 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, f:044 '%mil' Sandra Haggard, Regulatory Analyst Copy to: Bola Adeyeye,Operations Engineer, Office: 303-397-3606 II • -Daily Activity and Cost Summary_sls rr;EwuY Well Name: Middle Ground Shoal C24-23 INJ API/UWI Location Field Name Permit Number State/Province Well Configuration Type 50733201450100 TO8N-R13W-S23 Middle Ground Shoal 168-107 Alaska Directional Original KB Elevation(ft) Gr Elev(ft) KB-Ground Distance(ft) Spud Date Rig Release Date Total Depth(ftKB) 9/11/1968 11/19/1968 9,555.0 Jobs Job Category Primary Job Type/Initial Job Type Secondary Job Type/Final Job Type Start Date End Date Well Maintenance Tubing Change/Rpr 1/25/2013 00:00 2/25/2013 00:00 Objective Repair tubing-casing pressure communication.Pull tubing&slicklike fish,install new injection tubing&packer. Summary Daily Operations Rpt No. Report Start Date Report End Date Operation Summary#1 1.0 1/25/2012 1/26/2013 0000 Build and connect Hi-pressure mud line,flow line,choke manifold to mud pit lines, Cleaning Mud Pits&installing steam coils Cut drlg line Remarks#2 300 jts 3-1/2"Drill pipe,20 HWDP&10 4-3/4"DCs off-loaded Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 2.0 1/26/2013 1/27/2013 0000 Take on FIW to pits&heat to 120 degrees Weight up FIW w/CaCl2 to 11.4ppg 1900 Pump 255 bbl of 11.4ppg kill weight brine to get 11.4 returns @ 7000' Monitor well-flowing Bullhead 17 bbs down Tbg Monitor well-flowing Remarks#2 Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 3.0 1/27/2013 1/28/2013 0000 Circ&weight up to 11.5+ Monitor well-flowing Bullhead 14 bbls down Tbg to 9,300' Monitor well-OK 1300 Set BPV Nipple down tree&surface safety valve 2200 N/U Riser Remarks#2 PVT in use Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 4.0 1/28/2013 1/29/2013 0000 N/U Riser&BOPs 1430 Test annular to 250/2500psi Attempt to test pipe rams,threads leaking on hanger,pull BPV&install 2-way check valve,@ 4800 psi lost all pressure,attempt to retrieve 2-way check(not there) Notify AOGCC-got waiver to pull hanger&install test plug-retrieved 635'of tubing(checking for NORM) Cont.test BOPs 250/5000 psi Remarks#2 BOPs installed Tbg highly corroded with heavy scale build up on ID Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 5.0 1/29/2013 1/30/2013 Cont.Test BOPS to 250/5000 psi. PU spear fishing tool with drill pipe to retrieve wire line.Made trip to 555'and came out without fish. TIH with spear and washed to 586'.Broke rat hole when installing kelly repairing rat hole. Remarks#2 DP in use Construction Summary#3 www.xtoenergy.com Page 116 Report Printed: 8/26/2013 • •Daily Activity and Cost Summary_sls t ti GI Well Name: Middle Ground Shoal C24-23 INJ API/UWI Location Field Name Permit Number State/Province Well Configuration Type 50733201450100 TO8N-R13W-S23 Middle Ground Shoal 168-107 Alaska Directional Original KB Elevation(ft) Gr Elev(ft) KB-Ground Distance(ft) Spud Date Rig Release Date Total Depth(ftKB) 9/11/1968 11/19/1968 9,555.0 Daffy Operations Rpt No. Report Start Date Report End Date Operation Summary#1 6.0 1/30/2013 1/31/2013 Finished fixing rat hole. POOH with spear assy,no fish. Modified spear and TIH.POOH with spear,no fish.No evidence of WL fish;spear was entering inside tbg. PU overshot assembly and TIH.POOH.Fish on:3 jts tbg(94.46'). TIH with overshot.POOH.Fish on: 14 joints tbg(472.62). Remarks#2 Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 7.0 1/31/2013 2/1/2013 TIH with mill,junk basket,magnets.Tried to pump and jets plugged.POOH to unplug jets.Unplugged ports. TIH and washed down and tagged at 1236'.POOH. PU overshot assembly and TIH.Work overshot on fish.POOH with fish. Remarks#2 Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 8.0 2/1/2013 2/2/2013 POOH with fish.Recovered 6 joints(187.81').The last joint was pulled apart about 1'from the collar.LD fishing tools. PU milling assembly.TIH and washed down to fish and milled 3'of fish.POOH. PU overshot assembly.TIH.Work overshot on fish and PU.Jars did not go off.POOH with fish and LD 10 1/4 joints(325.52'). PU milling assembly and TIH.Clean out hole and polish off top of tubing fish. Remarks#2 Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 9.0 2/2/2013 2/3/2013 TIH with mill assembly,PU 10 more joints to get to 1715'. Hole was packed with coal/sand mix and came over shakers in large pieces.Milled 3'.POOH to change BHA. PU overshot assembly and TIH to fish.Sat down 15K and PU 40K,sat down 15K and PU 40K,jars went off and fish came loose.Did not get any stretch out of tubing.POOH with fish.LD fish 5 jts (134.59'). PU milling assy and TIH to clean out and polish top of fish.Send sweeps.POOH to change BHA. Remarks#2 NALCO chemical analysis showed samples were FeS,not coal and sand. Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 10.0 2/3/2013 2/4/2013 Cont.POOH to change BHA. PU overshot assembly.TIH and tagged fish at 1887',while circulating.Sat down with 15K,PU and jars went off 7x @ 75K,2x @ 85K,2x @ 100K,2x @ 110K,before releasing fish.POOH with fish.Fish:10 joints tubing(305.72').Last joint came apart in the middle.LD overshot assembly. PU milling assembly.TIH,tagged fish at 2193',milled 1'.Pump seep and cleaned hole.POOH to change BHA. PU overshot assembly.TIH.PU kelly and wash down to fish. Remarks#2 Construction Summary#3 www.xtoenergy.com Page 2/6 Report Printed: 8/26/2013 • fri.111111:NEHGY • Daily Activity and Cost Summary_sis Well Name: Middle Ground Shoal C24-23 INJ APINWI Location Field Name Permit Number State/Province Well Configuration Type 50733201450100 TO8N-R13W-S23 Middle Ground Shoal 168-107 Alaska Directional Original KB Elevation(ft) Gr Elev(ft) KB-Ground Distance(ft) Spud Date Rig Release Date Total Depth(ftKB) 9/11/1968 11/19/1968 9,555.0 ,Daily Operations Rpt No. Report Start Date Report End Date Operation Summary#1 11.0 2/4/2013 2/5/2013 Sat down on fish with overshot.Could not catch fish. POOH and found a few pieces of tubing in the junk basket. PU milling assembly and TIH to 2193'and continued to mill tubing with RPM 100,Weight at 1K to 2K. Equipment broke down(see notes). Cleaned off the floor and continued milling operation.While milling,the mill would not take any weight. Sweep hole and POOH with mill.After the sweep was finished,the cuttings auger quit working. Start BOP testing while fixing auger. Remarks#2 Equipment BD summary:Spinner locked up and a clevis broke.No one was hurt and the driller was fast to stop the rotary table so the hoses remained in place.After close examination of the spinners,we realized that they needed to be taken off to allow us to use the rotary table.After securing the well,broke off spinner and removed the same. Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 12.0 2/5/2013 2/6/2013 Testing BOPs.Finish testing at 13:30. PU&TIH w/wash pipe assembly,to include,shoe,XO,deltide cutter 5.56"OD X 4.25"ID,XO,5 ea washpipe 5.75"OD X 4.75"ID,drive sub,2 ea string magnets,Dailey bumper sub,Dailey Jars.TIH was slow due to U-tubing of the fluid. Tagged the fish at 2209'and washed to 2282',where the washing over jammed.Pump 10 bbl gel sweep and tried to continue washing over without success.Set down 35K and could not wash over any more. V POOH with fish.The fish on the top was jammed under the collar and wouldn't allow the pipe to go. Total fish 89.12'. Remarks#2 Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 13.0 2/6/2013 2/7/2013 Laying down wash pipe and fish 89.12'. PU overshot assembly with two string magnets next to overshot and the bumper sub,jars.TIH and found fish at 2321',sat down 15K and pulled up.No fish.Sat down 15K and made slight turn.PU 10K and had fish. POOH with fish.Had two pieces that added up to 30.08'.Last piece was split,but sound on the end. PU overshot assembly.TIH with overshot assembly.Tagged up at 2328',sat down 7K and pump pressure came up.PU 10K and broke free. POOH with fish.LD fish, 14 joints(412.11').Took fish out of overshot,laid down overshot tools. PU milling tools and TIH.Hit solid fill at 2300'and had 26'of hard fill.RPM 100,WOB 15K. Remarks#2 Received 2 cuttings tanks Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 14.0 2/7/2013 2/8/2013 Circulate sweeps around until the hole is clean. POOH to change BHA.Clean off magnets and LD milling assembly. PU overshot assembly and TIH.Tagged fish at 2740',PU 20K over and the fish was free with 3K over. POOH with fish.LD fish,7-3/4 joints(211.31').Last joint was pulled apart.LD overshot assembly. PU milling assembly and TIH.Clean out the hole for 20 minutes after each joint drilled down.Tagged fish at 2948',circulated sweep and cleaned hole.POOH. PU overshot assembly and TIH.Tagged fish with overshot and grabbed on to fish.POOH. Remarks#2 Construction Summary#3 www.xtoenergy.com Page 3/6 Report Printed: 8/26/2013 gaily Activity and Cost Summary_sls • ENERGY Well Name: Middle Ground Shoal C24-23 INJ APINWI Location Field Name Permit Number State/Province Well Configuration Type 50733201450100 T08N-R13W-S23 Middle Ground Shoal 168-107 Alaska Directional Original KB Elevation(ft) Gr Elev(ft) KB-Ground Distance(ft) Spud Date Rig Release Date Total Depth(ftKB) 9/11/1968 11/19/1968 9,555.0 Daily_Operat10fi3 . Rpt No. Report Start Date Report End Date Operation Summary#1 15.0 2/8/2013 2/9/2013 POOH with fish.Twisted metal jammed in overshot,no other fish. TIH with new overshot.Washed over fish pressure came up 100 psi and torqued up,got 3 rounds back, sat on it with 15K.PU with no overpull.POOH.No fish.When examining the overshot,discovered that the rubber on the packoff was torn.LD overshot assembly. PU wash pipe,which includes the following:5 3/4"shoe,4 each,5 3/4"wash pipe,drive sub,2 each 3 1/2"string magnets,Daily Bumper,Dailey Jar.TIH.Washed down at 2934'and tagged at 2952'. Washed down to 3078'.Circulated sweeps until hole was clean.POOH.LD wash pipe and cleaned off magnets(filled a gallon bucket of pieces of tubing when cleaning magnets). PU overshot and TIH.Filled pill pit with 40 bbls water and started mixing 6 sacks of Flo-Vis for gel sweeps as per instructions. i Remarks#2 Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 16.0 2/9/2013 2/10/2013 Cont.TIH with overshot.Tagged fish at 2949',Sat down 15K and work pipe.PU 60K over,set off jars and the fish came free.POOH and LD fish.Recovered 75. Re-dress overshot.Service rig.TIH with overshot.Tagged fish©3024'with 15k dn.Work fish,pulled 50k over and fish came free©10k excess weight.POOH and LD fish,recovered 1,293'. Adjust draw-works brakes. TIH with clean out assembly.Clean out f/3008'-V 3163' Remarks#2 Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 17.0 2/10/2013 2/11/2013 Wash f/3173'-t/4302',getting good amount of cuttings back,Brine 10.5 ppg,Vis 47.POOH.Service rig. TIH with overshot,wash f/4302'-t/4312,Engage fish,Jarred up twice©60k over,pulled free w/80k over.25k excess weight.POOH. Remarks#2 Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 18.0 2/11/2013 2/12/2013 Cont.POOH and LD fish,check for norm(OK).Recovered 3769'of fish,all the tbg,pkr and seal assembly.3-1/2"tbg stub sheared off in SBR seal assembly. RIH w/6"hollow mill and 7"casing scraper,pick up DP and breaking circulation.Tagged fill @ 8034'. Wash t/8060'top of Pkr.Circ 40 bbl Hi-Vis sweep&clean hole. Remarks#2 Tbg was in good condition,scale build up on ID to about 1-1/2"opening. Some slickline in the tbg starting©5000' Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 19.0 2/12/2013 2/13/2013 Slip&Cut drilling line. POOH w/clean-out assembly.Test BOPs.Service rig.RIH w/RTTS and test 7"casing from 8032'to surface w/2000 psi for 30 minutes.OK.POOH Remarks#2 Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 20.0 2/13/2013 2/14/2013 Cont.POOH w/RTTS.Nipple up shooting flange.Run 40 finger caliper&magnetic casing inspection logs in the 7"casing. NU drilling nipple.RIH&set retrievable bridge plug @ 1020',spot 500#sand on top.POOH. MU 7"casing cutter.TIH&cut casing @ 71'.POOH and LD cutter. ND BOPs. Remarks#2 Construction Summary#3 www.xtoenergy.com Page 416 Report Printed: 8/26/2013 • tally Activity and Cost Summary_sis rt~Lta(Y Well Name: Middle Ground Shoal C24-23 INJ API/UWI Location Field Name Permit Number State/Province Well Configuration Type 50733201450100 TO8N-R13W-S23 Middle Ground Shoal 168-107 Alaska Directional Original KB Elevation(ft) Gr Elev(ft) KB-Ground Distance(ft) Spud Date Rig Release Date Total Depth(ftKB) 9/11/1968 11/19/1968 9,555.0 :Daily Operations Rpt No. Report Start Date Report End Date Operation Summary#1 21.0 2/14/2013 2/15/2013 Finish N/D BOPs.Remove old well head.N/U wellhead.N/U BOPs. Remarks#2 Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 22.0 2/15/2013 2/16/2013 Finish ND BOPS. Set inflatable packer @ 44'.Test lower casing spool flange to 2000 psi for 30 minutes.OK.Packer would not deflate.Wait on perf gun&perf to deflate. Install 7"casing rams. Remarks#2 Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 23.0 2/16/2013 2/17/2013 Test upper casing spool flange&7"rams to 3000 psi(OK). Spear casing @ 73'.While putting in left-hand torque for back-off casing un-screwed @ 634'.LD casing.Wait on 13 joints of new casing.MU skirted joint&RIH w/casing Remarks#2 Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 24.0 2/17/2013 2/18/2013 Circ.to clear threads of debris.Screw casing together w/7000 ft/lbs torque.Pull test to 200k.Pressure test to 2000 psi for 30 minutes(OK). PU BOPs and set casing slips w/160k(string weight above cement).Cut casing.Nipple down BOPS. NU tbg spool.Test seals t/250/3000 psi for 15 minutes(OK).NU BOPs,install VPRs and test w/2-7/8" tubing to 250/5000 psi.Test wing valve on tbg spool to 2000 psi.. MU overshot and RIH Remarks#2 Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 25.0 2/18/2013 2/19/2013 Retrieve bridge plug©1011'. RIH w/6"Junk mill.Tagged©8020'.Ream f/8020'-T/8054'.POOH.Clean junk baskets and magnets.Showed signs of posible under-sized casing.RIH w/wireline spear. Remarks#2 Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 26.0 2/19/2013 2/20/2013 POOH found nothing on spear. Started BOP testing procedure.Finished BOP tests at 18:00.All tests passed. Rigged up wire line to run compression block,tagged fish at 8061',sat down on fish 3 times and POOH.Compression block had a 1-1/2"rope socket impression sticking up. Attempt to fish w/JDC pulling tool.RIH with tool and PU with 50#extra weight,no fish.Attempt to fish once more with 1-1/2"grapple.TIH and sat down on fish and pulled up 750#extra.Did not want to set off jars,PU and fish slipped off.TOOH.Rigged down wire line unit. PU Fishing tools to include 5 3/4"overshot W/1 1/2"grapple,Bumper sub,Oil Jars, 10 DC,17 HWDP. Remarks#2 Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 27.0 2/20/2013 2/21/2013 PU 5-3/4"overshot assembly with 1-1/2"grapple,bumper sub,oil jars, 10 DC, 17 HWDP.TIH to 7992. Wash down over fish to 8073'.POOH with overshot assembly.Retrieve fish&remove the same from overshot.Recovered all wire line tools. PU clean out assembly and TIH to 8015'MD.Wash down and mill from 8073'to 8075'MD.Sweep hole 2x with MP#1.Check for flow,lay down single and POOH. Remarks#2 Construction Summary#3 www.xtoenergy.com Page 5/6 Report Printed: 8/26/2013 • 'Lily Activity and Cost Summary_sIs ES Ell°11G Y Well Name: Middle Ground Shoal C24-23 INJ API/UWI Location Field Name Permit Number State/Province Well Configuration Type 50733201450100 TO8N-R13W-S23 Middle Ground Shoal 168-107 Alaska Directional Original KB Elevation(ft) Gr Elev(ft) KB-Ground Distance(ft) Spud Date Rig Release Date Total Depth(ftKB) 9/11/1968 11/19/1968 9,555.0 Daily Open._ ns Rpt No. Report Start Date Report End Date Operation Summary#1 28.0 2/21/2013 2/22/2013 Finish POOH with milling assembly. Cellar and wellhead room was had fluid due to leaking flow nipple,had to remove flow nipple and weld to refit for drip pan installation. PU 7"X 2 7/8"guide shoe on DP and make dummy run.Tagged up at 8075 and sat down on packer 3 times,pumped 30 bbl sweep and cleaned hole.Not tight spots when RIH.Pulled wear ring and rigged up to run completion packer assembly.Started running completion as per Olgoonik completion representative and well plan. Remarks#2 Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 29.0 2/22/2013 2/23/2013 PU 264 joints of 2 7/8"6.5#L-80 8 round EUE tubing with new guide shoe assembly and place same inside 7"casing.Tagged up on 3.25'of 264th joint,or 8055'of measured tubing(see notes on tubing tally). RU BJ to pump pickle acid job on tbg. Remarks#2 Picked up original strap and checked it with computer run strap,all measurements were correct.Had toolpusher,Olgnook completion representative,and XTO drilling foreman check figures with calculators.Figures were all the same.Called XTO Production Superintendent,to work on plan forward.Decided to move forward with BJ pickle job on the tubing. Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 30.0 2/23/2013 2/24/2013 Pump 500 gal of pickle acid(10%HCI w/adds)down tubing and follow with 32 bbls CaCL2 water to within 500'of the end of tubing.Reverse out acid and send to tank w/1,000 lbs soda ash.Repeat process with 500 gal of pickle acid.Used 1,000 gal acid total.RD BJ. RU wireline unit.Run wire to 8055'(profile nipple)which puts us on bottom.POOH with wireline and rig down wireline unit. Displace with 40 bbls clean 10.1 CaCl2 fluid and mix 260 bbls with 60 gal EC1447WR corrosion inhibitor and pump down tubing,to be followed with 50 bbls clean filtered(2 micron)CaCl2 fluid.Pull 3 joints and install space out pups 2 ea 10', 1 ea 4', lea 2'.Install 1 joint on top then hanger and landing joint. Remarks#2 WL depth measurement confirms tubing tally was wrong and the completion was set on depth. Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 4.0" T 31.0 2/24/2013 2/25/2013 Land hanger and run in lock-down screws. °" Drop bar for RHCP,test tubing to 1000 psi for 15 min,pressure up to 4000 psi to set packer,hold 4000 psi on tubing for 30 minutes,test was good.Test annulus to 2000 psi and record results for 30 minutes (OK). RU wireline and run 2"pulling tool at 8057'and pull prong.POH with prong. RIH with 2-1/2"GS pulling tool to 8060',pull RHCP plug body and POOH.RD wireline. Install BPV,ND BOP's,NU tree and test to 5000 psi for 15 minutes(OK). eleased rig from C24-23 to C34-26 at 00:00 02/25/2013. • Remarks#2 Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 32.0 2/25/2013 2/26/2013 Remarks#2 Construction Summary#3 www.xtoenergy.com Page 6/6 Report Printed: 8/26/2013 £I.OZ/93/8 :pa;uud;aodaa L/l. a6ed woo•A6Jeueo;x•MM ■ £#fuewwnS uogowlsu00 1101100IU1 uMOp 1nys'sninuue 6u!gn;o;uo!;eo!unwwoO'6u!;oafu!pewnsw uol;onpoJd 'einssaad go peen (>lo)s0;nulw g a0;ploy pue!sd 000Z 01 snlnuue'(ylo)!sd 0009 0;6u!gn1 uo dn einssald o6e1s',6908 aldd!u NX U!lees o1 6nid peddap`uo!;eo!unwwoo Jelnuue dots pue aa>ioed;as o;ldwal;e 01E3-1730 uo f1N Z#s>laewaa 'uo!loeful uo uaLM uo!1eo!unwwoo seq!IRS'aa>loed p04sa1- eu!laa!M uMOp 6!1j- 'aloy Jo no Ilnd'1OO14sal-N land'8 yolel 'vnM.3908 olio();6u!Ilnd Oaf z y1!M Ploy u!unu- 'OU!lanM dn 6!11- 'go peen dwnd uMOp lnys'aalloed;o 6u!1;as alaldwoo Ailn;ado14 o;ISd 0009 011004 1x°1-N uo uMOp painssaJd 6u!I1!J0- uogoafu!y1!M 01014 uMOp eseyo pue 1004lsal-N 2/L-3 doia- Ne0l bugeb!;senul 'uogeownwwoo bu!seo/6u!gni dJdL14 p./0C uo!}oalu!uo 1na seM Ila/N`OW!1 ley;;e palsa;seM Jalloed' peleidwoo;snf seM IIOM- £L0Z/8/£ £l 0Z/8/£ 0' 1#tiewwnS uollWed0 ales pu3 yodeH Plea Pe1S uodeN ON 141 suelle.led©Iciiea tiewwns Neel Javed loogsalgnw; Ioo;4SOl-N unb enlloefgo 0000£L03/9/C 00:00£1.0Z/8/£ Oug>lo!IS a0ueuelu!en 119M ales Pu3 ele0 VMS edAl qof lewd/edktl qof/Jepuooas edit qof PPP!/adAj qof tiewud tio6ele0 qof 0'999'6 8961./6 IA l 9961./1.146 (e>w)41dea leloi Plea eseeleN 6iN Plea PndS (8)aoueisla pun0.10-8) (4)A013 J0 (B)uogeA013 S>I leu16110 Ieuo!loana e>lsely LO L-991, 1e014S punwo OIPP!W £3S-M£LN-N801 001.09V1.0Z££L09 adAi uolleJn611u00 IIaM aoulnwd/aleIS ewers!Pleld uogeool IMn/IdV f NI £Z-tZ3 IBoLIS punoio aIPP!IN :eweN IIaM AD-agNaff s — ewwns }sod pue ftwupy AIie(410 OIIIIIIC XTO *ally Activity and Cost Summars ERGY Well Name: Middle Ground Shoal C24-23 INJ API/UWI Location Field Name Permit Number State/Province Well Configuration Type 50733201450100 TO8N-R13W-S23 Middle Ground Shoal 168-107 Alaska Directional Original KB Elevation(ft) Gr Elev(ft) KB-Ground Distance(ft) Spud Date Rig Release Date Total Depth(ftKB) 9/11/1968 11/19/1968 9,555.0 Jobs r Job Category Primary Job Type/Initial Job Type Secondary Job Type/Final Job Type Start Date End Date Well Maintenance Repair Packer Leak 5/10/2013 12:00 5/23/2013 00:00 Objective Summary Daily Qeraions Rpt No. Report Start Date Report End Date Operation Summary#1 1.0 5/10/2013 5/11/2013 Prep to skid rig.Change out Annular preventer element.Skid rig south. Unplug electrical. Remarks#2 Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 2.0 5/11/2013 5/12/2013 Disconnect electrical. Skid rig to Leg#4 onto C24-23. Install handrails.Clean Leg#1 deck.Secure rig w/storm clamps.Safety meeting on helicopter safety.Connect service lines.M/U mud line,4"&6" choke manifold return lines.Organize decks. Remarks#2 Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 3.0 5/12/2013 5/13/2013 Connect electrical&test run equipment assignments.Finish R/U flow line,cat-walk,finish hand rails, move belly finger in derrick for tubing.Test mud lines.&organize decks and rig.R/U&E-line and perf tubing 7,933'to 7,936'. Remarks#2 Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 4.0 5/13/2013 5/14/2013 Kill well w/10.1 brine.Monitor well(Static).Set BPV. N/D wellhead. N/U&test BOPs. Pull 2-way check. Back out lock down screws. Pull hanger and attempt to pull retrievable packer free. Rotate tubing 25 turns and packer came free w/10k over-pull. Remarks#2 Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 5.0 5/14/2013 5/15/2013 Continue to POOH with 2 7/8"completion assembly from 2,268'to packer assembly. Lay down packer and send same to shop for repair.Service rig.Pick up Halliburton RTTS and TIH to 7,949'MD and RU to circulate 2X DP volume and then fill up DP with FIW.SET RTTS at 7,949',where the packer was set, and test 7"for 30 minutes at 2,000 psi.Test was good.Start to pump down DP and inject at 3,500 psi for 30 minutes. 17 bbls FIW was injected,with no increased pressure on the 7"annulus.Charted both tests.Released RTTS and moved up 30'to repeat tests at 7,919'MD.Set RTTS and repeated tests with the same results. No communication between annulus and DP. Reversed out FIW back to pits and displaced hole with kill mud. Prepared to start laying down DP.Checked for flow for 10 minutes.Static. TOOH with RTTS assembly while laying down DR Remarks#2 Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 6.0 5/15/2013 5/16/2013 Continue laying down DP to RTTS and send tools on boat. RIH with drill pipe in derrick,open ended. Kelly up and soft break kelly valve. Remove spinners from kelly,stand back kelly in sock. Drain stack and check DP for center of wellhead.Continue laying down DP. Pull wear ring. Level derrick to center of wellhead. Rig up completion handling equipment. Pick up completion packer assembly and RIH with same.Continue RIH with 2 7/8"completion tubing.Spot slick line unit on catwalk.Clean pits in preparation for fluids needed for completion. Remarks#2 Construction Summary#3 www.xtoenergy.com Page 1/3 Report Printed: 8/26/2013 *ally Activity and Cost Summarys Etro NERGY Well Name: Middle Ground Shoal C24-23 INJ API/UWI Location Field Name Permit Number State/Province Well Configuration Type 50733201450100 TO8N-R13W-S23 Middle Ground Shoal 168-107 Alaska Directional Original KB Elevation(ft) Gr Elev(ft) KB-Ground Distance(ft) Spud Date Rig Release Date Total Depth(ftKB) 9/11/1968 11/19/1968 9,555.0 Daily Operations Rpt No. Report Start Date Report End Date Operation Summary#1 7.0 5/16/2013 5/17/2013 RIH with 2 7/8"tubing,tagged tubing at 8,075 MD.Space out as per Oglenook representative. Land hanger and lock down. Drop bar and rig up to set packer with test pump.Pressure up on tubing to 1,000 psi for 15 minutes,continue to pressure up to 4,000 psi and hold for 30 minutes.Packer.,did not „,§ ,..continued to pressure up to 5,300 psi before packer set.Test annulus for 30 minutes at 2,000 psi. Rig up slick line and RIH with tool to open sliding sleeve,open sieve and POOH with tool.Rig up to displace tubing with 50 bbls of FIW. Rig down circulating swedge and rig up slick line and RIH with tool to close sliding sleeve. Pressure up to 1,000 psi for 15 minutes to verify sliding sleeve is closed. Install retrieving tool on slick line to retrieve bar.POOH with bar. Plan forward:After bar is out,Start injection test at 3,500 psi for 30 minutes to insure packer integrity. Drop bar,open sliding sleeve and reverse out FIW and replace with 10.1 lb/gal fluid.Set BPV and ND BOPE and NU WH.Set two-way check and test to 5,000 psi. RU slick line,Open sliding sleeve and set in FIW packer fluid.Close sliding sieve. PWOI and monitor annulur pressure.SWI. RD derrick and release rig. Remarks#2 Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 8.0 5/17/2013 5/18/2013 POOH with bar.Attempted to inject FIW;packer failed at 3,500 psi. Pressure was migrating to the 7" annulus at 1,200 psi.Dropped bar and retested tubing to 4,000 psi.Test was good. RU slick line and RIH to open sliding sleeve.Reverse circulate to displace FIW with kill mud that was 10.1 ppg. Communication with production superintendent resulted in dropping bar and retest annulus to 2,000 psi with sliding sleeve open.Test was good. RU slick line and retrieved bar and seat. RU Pollard E-line unit and RIH with 2.25"jet cutter;cut tubing at 7,886'WLD. POOH and RD Pollard tools and equipment. Cameron unlocked hanger,laid down the same.TOOH with 2 7/8"tubing to 7,810'MD.Service rig, clean floor and prepare for new packer. Plan forward:Wait for new packer from Baker. If they get it ready today we will install the same.Talked to Baker yesterday and they thought that the packer assembly might not be ready until)Sunday. Remarks#2 Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 9.0 5/18/2013 5/19/2013 Set wear bushing;lay out and strap 3 1/2"DP and start picking up the same. Make up the RTTS to DP and single in the hole, picking up off the cat walk.Tag top of tubing stub at 7,882'MD. Pick up 100'to 7,872'MD,displace DP volume with FIW;Set RTTS and inject at 0.5 bpm and 3,500 psi for 30 minutes.Test was good and 7"casing pressure remained the same.Unseat RTTS and reversed out the FIW to pits with 10.1 ppg kill mud.Checked for flow fo 10 minutes. No flow.TOOH with RTTS. Plan forward: Lay down RTTS, PU overshot with 2 7/8"mill.TIH with mill and dress up 2 7/8"stub. POOH with mill and PU new packer and TIH with packer assembly and 2 7/8"tubing. Remarks#2 Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 10.0 5/19/2013 5/20/2013 POOH with RTTS.Breaks on drawworks was not working properly. Hang blocks and changed out break bands.Continued TOOH with RTTS and laid down same.Make up overshot mill and RIH to 7,854'. Kelly up and circulate BU.Wash down and mill top of tubing to 7,885 MD. Blow down kelly and stand back.Make up 4'pup and a single.Slack off over tubing. RU slick line to drift with 1.85"to 8,082 WLD. POOH and rig down slick line tools and equipment.Check for flow.Static.TOOH with overshot assembly. Plan forward: Finish TOOH. Lay down overshot mill assembly. Perform BOPE test.Witness waived by James Regg of AOGCC.Pick up new Baker packer and follow completion procedures. Remarks#2 Construction Summary#3 www.xtoenergy.com Page 2/3 Report Printed: 8/26/2013 O •aily Activity and Cost Summar'yils PCTNERGY Well Name: Middle Ground Shoal C24-23 INJ API/UWI Location Field Name Permit Number State/Province Well Configuration Type 50733201450100 TO8N-R13W-S23 Middle Ground Shoal 168-107 Alaska Directional Original KB Elevation(ft) Gr Elev(ft) KB-Ground Distance(ft) Spud Date Rig Release Date Total Depth(ftKB) 9/11/1968 11/19/1968 9,555.0 Daily er ion _ _ _ � Rpt No. Report Start Date Report End Date Operation Summary#1 11.0 5/20/2013 5/21/2013 Finish POOH with mill assembly,lay down the same.Pull wear ring,rig up testing equipment to test BOPE.Test BOPE,27/8"and 3 1/2"pipe @ 250 psi/5,000 psi:Test Annular preventer 250 psi/2,500 psi. Rig down testing equipment.Make up Baker retrievable packer assembly and run in hole with 2 7/8"6.5#L-80 8 round tubing.Continue single in hole with completion tubing:space out as per Baker Representative.Pick up hanger and land:Cameron rep to lock down same. Rig up slick line and TIH with 1.88"to 7,877'WLD:Verify depth of XN plug. POOH with slick line.Take out 2'pup and reset hanger. Plan ahead: Drop bar and pressure up to set packer.Test tubing to 4,000 for 30 minutes.Test annulus to 2,000 for 30 minutes. RU slick line and TIH to open sliding sleeve.Pump 50 bbls FIW down tubing. TIH with slick line and close sliding sleeve,TIH with bar recovery tool and recover bar. Perform injection test @ 3,500 psi for 30 minutes.TIH to open sliding sleeve and reverse out FIW and replace with 10.1 CaCl2 fluid.Close sliding sleeve.Set BPV and ND BOPE.NU WH and test to 5,000 psi. Finish by Placing packer fluid in annulus and FIW in tubing.PWOI.Release rig to new well,move rig. Remarks#2 Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 12.0 5/21/2013 5/22/2013 Drop bar and set packer,test tubing to 4,000 psi for 30 minutes:test annulus to 2,000 psi for 30 minutes.Chart both.test was good. RU slick ling e to open sliding sleeve,displace tubing with FIW for injection test,close sleeve. Pressure up to verify sleeve is closed.RIH with slick line to pull bar.Start injection at 1/2 BPM at 3,500 psi.for 30 minutes. 20 barrels injected with no pressure noted on the 7"casing.Charted test.Pulled RHCP plug on slick line, RIH and set XN plug body and prong.Open sliding sleeve to reverse out FIW and replace with 10.1 CaCL2. Flow check well.Cameron to set BPV. Nipple down BOPE. Plan forward: Finish nippling up tree and testing to 5,000 psi. RU lines to pump FIW with packer fluid to be placed in the 7"annulus. Follow it with FIW in the tubing. RU slick line and close sliding sleeve,pull prong and XN nipple. Prepare to move rig to new well. Remarks#2 Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 13.0 5/22/2013 5/23/2013 Continue nipple down procedure. Nipple up WH and test to 5,000 psi.Test was good. Rig up to circulate packer fluid in annulus and FIW in the tubing.Displaced CaCl2 in the well with FIW. Blow down surface lines and rig down the same.RU slick line to close sliding sleeve,verify sliding sleeve is closed by pressuring up to 1,000 psi for 20 minutes.test was good.make two runs with slick line to pull plug and seat. Make preparations to move rig to C34-26. Plan forward:Move rig to C34-26 Remarks#2 Construction Summary#3 www.xtoenergy.com Page 3/3 Report Printed: 8/26/2013 1 + 0 w AAA 5-20-13 /TO ERGY Proposed Completion KB: 35' MGS C24-23 WIW i� Water Depth: 73' MSL Cook Inlet, Alaska Leg 4, Conductor 32 Completion API No.: 50-733-20145 r eft 4' Pup Jt, 2-7/8"6.5# 1% Cr 8rd @ 293' Spud: 11-24-68 A ; 2-7/8"X Nipple (2.313" ID) 9Cr @ 297' Sidetracked from C11-26 /J/ r_ 4' Pup Jt, 2-7/8"6.5# 1% Cr 8rd @ 298' 250 jts 2-7/8"6.5#L80+1% Cr 8RD EUE 24" Conductor Casing @ 370' 4' Halliburton Sliding Sleeve @ 7742' 4' Pup Jt, 2-7/8"6.5# 1% Cr 8rd @ 7747' 2-7/8"X Nipple (2.313" ID) 9 Cr @ 7751' 4' Pup Jt, 2-7/8"6.5# 1% Cr 8rd @ 7752' Surf Csg: 10 3/4", 40.5#, J55. 1 jt 2-7/8"6.5#L80+1% Cr 8RD EUE Set @ 1830', Cmt w/ 1300 sx. 7" Baker FH Retrievable Packer @ 7793' 4' Pup Jt 2-7/8"6.5#L-80 8rd @ 7800' 2 jts 2-7/8"6.5#L80+1% Cr 8RD EUE 6' Pup Jt, 2-7/8"6.5# 1% Cr 8rd @ 7863' 2-7/8"XN Nipple (2.205" ID) 9Cr @ 7870' 6' Pup Jt, 2-7/8"6.5# 1% Cr 8rd @ 7871' 3.5"x 2-7/8"TIW Overshot @ 7878' Lower Completion Installed 8-4-72 3-Y"Tbg stub top @ 8078' Otis 'X' Nipple(2.75" ID) @ 8981' Otis'Q' Nipple (2.635" ID) @ 8992' v; F. po 0 040... .. / 7"TIW HB-BP Permanent Packer.Failed 0:„, �_ during workover,cut pipe and run new 00, packer 0./I 3.5"x 2-7/8"TIW overshot @ 7878' Guiberson RH-1 pkr©8081' GN-GO: 8108' 8140' KBG Mandrel#1 @ 8233'Otis'XO'SS @ 8268'(closed) _ FS= `' Collapsed Csg 8120-30'. Repaired w/csg roller in running isolation packers. /� 1972 before ru g p Guiberson RH-1 pkr @ 8272' '% 01 — GR-GS: 8413'-8466' HC HD: 8702' 8709' KBG Mandrel#2 @ 8759'(dummy) HC-HD: 8720'-8758' Otis XO'SS @ 8795'(Open) 000 ��mm HD-HE: 8766'-8775' Guiberson RH-1 pkr @ 8799' /� KBG Mandrel#3 @ 8857'(dummy) �/ ■ HE-HF: 8824'-8865' Otis`XO'SS @ 8892'(Open) / ====� Tbg Punch @ 8910-20' Guiberson RH-1 pkr @ 8896' KBG Mandrel#4 @ 8932'(dummy) HI-HK: 8928'-8942' Otis`XO'SS @ 8967'(closed) /0,1_ HI-HK: 8955'-8967' Guiberson RH-1 pkr @ 8970' �M 7/ Longstring: 7" N80 Set @ 9530'. !9 HK-HN: 8985'-9110' 26# BTC-Modified: surf-634' / HN-HR: 9128'-9185' 26#BTC: 634' 8070'&29#BTC: Pr 0 — HN-HR: 9198'-9278' 8070'-9530'. /r 9 HR-HZ: 9312'-9333' PBTD: 9441'Cmt w/960 sx. TD: 9555' %��//III//d j HR-HZ: 9355'-9440' • Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Saturday, May 18, 2013 5:48 PM To: Adeyeye, Ajibola Cc: Griffith, Scott Subject: Re: XTO Energy C24 -23: Packer depth variance Request (PTD 168.107) : As we discussed you have approval to move packer depth to 7780 ft ( greater than 200 ft above injection zone) . Previous packer was already approximately 500ft above infection zone. Guy Schwartz An(rr N 0 4 aV4 Sent from my iPhone On May 18, 2013, at 1:19 PM, "Adeyeye, Ajibola" <A;ibota Adeyeyre, )xtoenergy.coni> wrote: > Msg Class:Unclassified > Guy - > > Referencing our earlier conversation. we didn't get a good infection test with the recent packer on MGS C24 -23 (PTD 168 -107). Had to cut above the packer and dress over fish. The plan is to run a different style retrievable packer. As a result, packer depth will be ^'630 feet above top perforation, new packer will be set at approximately 7780 feet. � I > Requesting variance to set packer at depth higher than 200 ft above top pert. > Regards > Ajibola (Bola) A. Adeyeye > XTO Energy —Subsidiary of ExxonMobil > Operations Engineer — Western Division > Office: 303 - 397 -3606 Cell: 720 - 539 -1660 • • Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Wednesday, May 15, 2013 4:04 PM To: 'Adeyeye, Ajibola' Cc: Griffith, Scott Subject: RE: XTO Energy C24 -23: Workover Procedure Update (PTD 168 -107) Bola, The change to a permanent packer is approved as well as the operation steps needed to implement the new completion ( as outlined below). It is very similar to the original proposed completion and can be implemented in the approved sundry 313 -221. Be sure and include the PTD number in all email correspondence to the AOGCC... Guy Schwartz Senior Petroleum Engineer AOGCC SCANNED �Al''�� 907 - 444 -3433 cell 907 - 793 -1226 office n From: Adeyeye, Ajibola il'3f�iIto .h� :!�;C ?�ca Adeyeye c�X�'JE�, �'rvv'.CC)i n Sent: Wednesday, May 15, 2013 2:27 PM To: Schwartz, Guy L (DOA) Cc: Griffith, Scott Subject: XTO Energy C24 -23: Workover Procedure Update Guy As per phone conversation, the packer pulled out of C24 -23 was in very bad condition and cannot be redressed. As a result, we will instead be running a permanent packer with sliding sleeve on top. We will attempt to simulate normal injection before nippling down the BOP, confirming packer isolation. The following steps will be sequentially added to workover procedure (after hydraulically setting the permanent packer): o Open sliding sleeve and circulate workover fluid out of tubing, displace with filtered injection water. Close sliding sleeve, pressure test to confirm isolation o Run slickline to pull bar out of XN- nipple. Resume injection test o Run blanking plug into XN- nipple, pressure test. Open sliding sleeve, reverse circulate 10.1 ppg CaCl into tubing o Nipple down BOP, set BPV. NU wellhead, pull BPV. Set 2 way check and pressure test wellhead o Circulate packer fluid down the tubing into tubing- casing annulus. Chase down with filtered injection water o Run sleeve closing tool on slickline, close sliding sleeve and pressure test to confirm sleeve closed. Retrieve blanking plug with slickline o Conduct pre- injection MIT. If passed, put well on injection Please let me know if further discussion is required. Will be expecting your response. Regards Ajibola (Bola) A. Adeyeye XTO Energy — Subsidiary of ExxonMobil • OF 77. 4 , 1 V/ .4' 6j, THE STAT • Alaska Oil and Gas .7 1 s OfA L A S KA GOVERNOR SEAN PARNELL 333 West Seventh Avenue OF Q. Anchorage, Alaska 99501 -3572 AL Main: 907.279.1433 SCANNED MAY 1 0 2313 Fax: 907.276.7542 Sandra Haggard Regulatory Analyst r / �� J 7 XTO Energy V 9127 S. Jamaica Street Englewood, CO 80112 Re: Middle Ground Shoal Field, E, F, & G Pool, Middle Ground Shoal C24 -23 Sundry Number: 313 -221 Dear Ms. Haggard: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the 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, / Cathy P. roerster Chair DATED this /1 day of May, 2013. Encl. f 0 STATE OF ALASKA • J 5 ?(V''', ALASKA OIL AND GAS CONSERVATION COMMISSION Pp DTS J1/0/0 /� APPLICATION FOR SUNDRY APPROVALS 20 MC 25.280 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well p , Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing is • Time Extension ❑ Operations Shutdown ❑ Re - enter Susp. Well ❑ Stimulate ❑ Alter Casing ❑ Other. ❑ 2. Operator Name: XTO Energy 4. Current Well Class: 5. Permit to Drill Number. Exploratory ❑ Development ❑ 168 -107 3. Address: 9127 S Jamaica St Stratigraphic ❑ Service 0 , 6. API Number. p143 Englewood, CO 80112 50 - 733 - 20145 - 011 7. If perforating: 8. Well Name and Number. What Regulation or Conservation Order govems well spacing in this pool? Will planned perforations require a spacing exception? Yes ❑ No ❑ Middle Ground Shoal C24 -23 . 9. Property Designation (Lease Number): 10. Field /Pool(s): ADL 18756 ' MGS E, F & G Oil Pools • 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): • 9,555 • 9,407 1 9,441 . 9,292 NA NA Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 1,830' 10 -3/4" 1,830' 1,812' 3,130 psi 1,580 psi Intermediate Production 9,530' 7" 9,530' 9,383' 7,240 psi 5,410 psi Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 8,108 - 9,440 . 7,973 - 9,294 2 -7/8" & 3 -1/2" L -80 w /1% Cr & N -80 8,081 & 8,992 Packers and SSSV Type: TIW 7" HM1 Retrievable packer, Packers and SSSV MD (ft) and TVD (ft): Guiberson 7" RH -1 packer, No SSSV Please see attachment 12. Attachments: Description Summary of Proposal El • 13. Well Class after proposed work: Detailed Operations Program is . BOP Sketch 0 . Exploratory ❑ Stratigraphic ❑ Development ❑ Service 0 c 14. Estimated Date for • 5/10/2013 15. Well Status after proposed work: Commencing Operations: Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: WINJ E • 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 Sandra Haggard Email Sandra Haggard(axtoenergy.com Printed Name Sandra Haggard Title Regulatory Analyst Signature 2 1 0 °•" ' ( Phone 303-397-3672 Date 5/6/2013 ■ COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 5 1 3 _ 2 ^ Plug Integrity ❑ BOP Test M Integrity Test Location Clearance p L Other: °� re l--- RBDMS MAY 10 201 7' a „I2r- • �.. GLGC. -43/ c..)( C) Spacing Exception Required? Yes ❑ No Subsequent Form Required: / Q _ [.{©L/ a zt7 APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: 5...../d _4 .7 r- 15 Submit Form and Form 10-403 (Revised 10/2012) App e i o i v li for 12 months from t date of approval. Attachments i D licate 11%01 h MAY 0 7 2013 E NERGY AOGCC May 6, 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 -403 for Well Operations for MGS C24 -23 Dear Mr. Norman, XTO Energy, Inc. hereby submits the Report of Sundry Well Operations Form 10 -403 for the MGS C24 -23 Please find enclosed the following information for your records: 1. Form 10 -403 Application for Sundry Approval 2. Form 10 -403 Attachment (packer depths) 3. Summary Page 4. Job Procedure 5. Current Wellbore Diagram 6. Proposed Wellbore Diagram 7. Approved Sundry #312 -259 (original workover sundry) If you require additional information, please contact me at (303) 397 -3672 Sincerely, ..42 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 XTO ENERGY MGS C24 -23 Form 10 -403 Attachment Packer depths ITEM MD (ft) TVD (ft) TIW 7" HM -1 Retrievable Packer 7,948 7,788 Guiberson 7" RH -1 Packer, #1 8,081 7,945 Guiberson 7" RH -1 Packer, #2 - 8,272 8,141 Guiberson 7" RH -1 Packer, #3 8,799 8,655 Guiberson 7" RH -1 Packer, #4 8,896 8,752 Guiberson 7" RH -1 Packer, #5 • 8,970 8,825 fto GY May 6, 2013 To: John Norman Guy Schwartz Victoria Ferguson CC: Scott Griffith Romeo Perez From: Alec Bridge RE: MGS C24 -23 Cook Inlet, Platform C 7" packer repair Addition to previously completed workover program XTO completed the workover on the MGS C24 -23 (Sundry #312 -259) to eliminate pressure on the casing - tubing annulus and install a new completion. A pre- injection MIT and tubing pressure test were performed, and both tests passed. When injection operations started, pressure began to build on the casing - tubing annulus. The pressure was bled off, injection operations were started again, and pressure again began building on the annulus. Injection operations were stopped once the pressure on the annulus reached 2,000 psi. The annular pressure would not bleed down over time with the tubing pressure; pressure had to be bled off manually at surface. The well is currently shut in awaiting packer replacement. A proposed workover procedure to repair the packer leak is attached. Please reference Sundry #312 -259 for the original scope of work, original workover pra edure,.._killweight- calculations,. BOPE drawings, etc. A copy of the original approved Application for Sundry Approvals is attached for your reference. If you require additional information, please contact me at 303 - 397 -3608. Sincerely, 0 ,6 r 4 ,,,, : o t eiyz 05 (0(0 / Alec Bridge Operations Engineer • • 1 fto GY XTO ENERGY INC. MGS C24 -23 EAST FLANK, COOK INLET, ALASKA PACKER REPAIR PROCEDURE Updated: 05/06/2013 WELL DATA SURFACE CASING: 10 -3/4 ", 40.5 #, J -55. Set @ 1,830'. Cmt w /1,300 sx. PRODUCTION CASING: 7 ", N -80, BTC. Set @ 9,530'. Cmt w/960 sx. Surf - 8,070': 26# 8,070' - 9,530': 29# PBTD: 9,441' UPPER COMPLETION: All tubing is 2 -7/8 ", 6.5 #, 1% Cr L80, 8rd, EUE (Installed February 2013) 2 -7/8" X Nipple (2.313" ID) @ 281' w /4' pup on top & bottom 2 -7/8" X Nipple (2.313" ID) @ 7,906' w /4' pup on top & bottom TIW HM -1 7" Retrievable Packer @ 7,948' 2 -7/8" XN Nipple (2.205" ID) @ 8,060' w /6' pup on top & bottom TIW OS @ 8,067' LOWER COMPLETION: 3 -1/2 ", 9.3 #, N80, 8rd, EUE 8,078' - 8,992' (Installed 1972) Guiberson RH -1 pkr @ 8,081' KBG Mandrel #1 @ 8,233' Otis `XO' sliding sleeve @ 8,268' (closed) Guiberson RH -1 pkr @ 8,272' KBG Mandrel #2 @ 8,759' (dummy) Otis `XO' sliding sleeve @ 8,795' (open) Guiberson RH -1 pkr @ 8,799' KBG Mandrel #3 @ 8,857' (dummy) Otis `XO' sliding sleeve @ 8,892' (open) Guiberson RH -1 pkr @ 8,896' KBG Mandrel #4 @ 8,932' (dummy) Otis AO' sliding sleeve @ 8,967' (closed) Guiberson RH -1 pkr @ 8,970' Otis `X' Nipple (2.75" ID) @ 8,981' Otis `Q' Nipple (2.635" ID) @ 8,992' PERFORATIONS: GN - GO: 8,108' - 8,140' (SS Closed) GR - GS: 8,413' - 8,466' HC - HD: 8,702' - 8,709' HC - HD: 8,720' - 8,758' HD - HE: 8,766' - 8,775' HE - HE: 8,824' - 8,865' HI - HK: 8,928' - 8,942' (SS Closed) Y:\ALASKA\Procedures \C24 -23 \C24 -23 Packer Repair 05- 06- 2013.docx • • 2 HI — HK: 8,955' — 8,967' (SS Closed) HK — HN: 8,985' — 9,110' HN — HR: 9,128' — 9,185' HN — HR: 9,198' — 9,278' HR — HZ: 9,312' — 9,333' HR — HZ: 9,355' — 9,440' BHST: 170 Deg F BHP: 4,500 psi (SI WHP = 600 psi) HOLE DEVIATION: Max 19 Deg f/ 3,400' — 3,700' MD SMALLEST ID: 2 -7/8" XN Nipple @ 8,061' (2.205" ID) CURRENT STATUS: Shut in OBJECTIVE: Repair packer leak NOTES: • AFE #1200482 • Workover to eliminate pressure on tubing x casing annulus (Sundry #312 -259) was completed in March 2013. A pre- injection MIT and tubing pressure test were conducted and both passed. When the well was ✓ put on injection, pressure immediately began to build on the tubing x casing annulus. Pressure would not bleed off the annulus when injection was stopped. • Annulus is currently filled with 10.1 ppg CaC12 fluid mixed with corrosion inhibitor. 1. RU derrick. Bullhead down tubing with 60 bbls filtered 10.1 ppg CaC12 fluid. Monitor well for 60 minutes to verify that well is dead. 2. Notify AOGCC 48 hours prior to BOPE test. Set BPV. ND tree. NU riser and BOPE. Pull BPV and set two -way check. Ensure that BOPE has VPRs for 2 -7/8" — 3 -1/2" pipe. Pressure test BOPE to 250 , psi and 5 000 s i" 3. Have Pollard WL on standby to cut tubing in case packer does not release. RU to POOH with 2 -7/8" completion. Release packer. Check for flow. Circulate bottoms up. POOH with completion. Send packer to be inspected and redressed. If the packer does not release, RIH with radial torch to cut tubing. Cut tubing at +/- 7,896' (middle of first full joint above packer). RIH with overshot and jars on drill pipe. Jar packer free. POOH 4. MU 7" RTTS packer on 3 -1/2" drill pipe. Ensure packer has bypass installed. When MU workstring, apply pipe dope to pin ends only. RIH to 7,949'. Before setting RTTS, flush DP with 2x drill pipe volume with filtered workover fluid (pump flush at as high of rate as possible to avoid washing rubbers off packer). Set packer at 7,949'. Open bypass and begin pumping down drill pipe with FIW. Y:\ ALASKA\Procedures \C24 -23 \C24 -23 Packer Repair 05- 06- 2013.docx • 3 After pumping drill pipe volume, close bypass and begin injecting (inject at 3,500 psi to simulate injection conditions). Monitor annulus for pressure and flow. If annular pressure increases, contact Alec Bridge before proceeding. If no pressure is observed on the annulus, stop injecting. Open bypass, and reverse circulate with 10.1 ppg workover fluid to circulate FIW out of the drill pipe. Check for flow. 5. With packer still set at 7,949', conduct a pre -MIT (will conduct a standard pre- injection MIT after completion has been installed). Pressure test annulus to 2,000 psi for 30 minutes. Release packer and POOH with drill pipe and packer. LD drill pipe when POOH. 6. RIH with 7" packer and completion as follows in table below (completion is identical to the old one.* except for running 4 full joints of tubing below the packer instead of 3; packer will be set at 7,923'). Apply pipe dope to pin ends only. Item Length, t Top Bottom 2 -7/8" 6.5# L80 + 1% Cr 8rd EUE 300 0 300 4' Pup Jt, 2 -7/8" 6.5# 1% Cr 8rd EUE 4 300 304 2 -7/8" X Nipple (2.313" ID) 9 Cr 1 304 305 4' Pup Jt, 2 -7/8" 6.5# 1% Cr 8rd EUE 4 305 309 2 -7/8" 6.5# L80 + 1% Cr 8rd EUE 7,572 309 7,881 4' Pup Jt, 2 -7/8" 6.5# 1% Cr 8rd EUE 4 7,881 7,885 2 -7/8" X Nipple (2.313" ID) 9 Cr 1 7,885 7,886 6' Pup Jt, 2 -7/8" 6.5# 1% Cr 8rd EUE 6 7,886 7,892 1 jt 2 -7/8" 6.5# L80 1% Cr 8rd EUE 31 7,892 7,923 ( 7" TIW HM -1 Retrievable Packer (13 Cr) 9 7,923 7,932 1� 4 jts 2 -7/8" 6.5# L80 1% Cr 8rd EUE 122 7,932 8,054 6' Pup Jt, 2 -7/8" 6.5# 1% Cr 8rd EUE 6 8,054 8,060 2 -7/8" XN Nipple (2.205" ID) 9 Cr (RHCP installed) 1 8,060 8,061 6' Pup Jt, 2 -7/8" 6.5# 1% Cr 8rd EUE 6 8,061 8,067 3 -1/2" x 2 -7/8" TIW SBR (13 Cr) 7 8,067 8,074 7. Prior to spacing out and landing completion, pump 100 bbls workover fluid down tubing. Mix 260 bbls workover fluid with 60 gal EC1447 (corrosion inhibitor) and pump down tubing. Displace with 50 bbls clean, filtered CaC12 fluid. 8. Space out and make up and land tubing hanger. 9. Drop bar (will seat in RHCP in XN- nipple). Pressure test tubing to 1,000 psi for 15 minutes. Continue to pressure up to 4,000 psi to set packer (follow TIW's setting instructions). Pressure test tubing to 4,000 psi for 30 minutes. 10. Conduct pre- injection MIT to 2,000 psi for 30 minutes. Chart the MIT. Y:\ ALASKA\Procedures \C24 -23 \C24 -23 Packer Repair 05- 06- 2013.docx • • 4 11. Set BPV. ND BOPE. NU WH. Pull BPV. Set two -way check. Test wellhead to 5,000 psi. Pull two - way check. 12. RU SL. RIH and pull bar and RHCP. RD SL. 13. Prior to RD derrick, PWOI and monitor annular pressure. SWI. RD derrick and release rig. 14. PWOI. Alec Bridge Oi "v ` / 05/o6/2013 Operations Engineer Y:\ ALASKA\Procedures \C24 -23 \C24 -23 Packer Repair 05- 06- 2013.docx • • • ACB 3 -5 -13 TO ENE RGY Current Completion KB: 35' MGS C24 -23 WIW � Water Depth: 73' MSL Cook Inlet, Alaska • Leg 4, Conductor 32 rt. Completion Installed 2- 24 -13: API No.: 50- 733 -20145 4' Pup Jt, 2 -7/8" 6.5# 1% Cr 8rd @ 278' Spud: 11 -24 -68 2 -7/8" X Nipple (2.313" ID) 9Cr @ 282' Sidetracked from C11 -26 11-24-68 A 2-7/8" 4' Pup Jt, 2 -7/8" 6.5# 1% Cr 8rd @ 283' 250 jts 2 -7/8" 6.5# L80 +1 % Cr 8RD EUE 24" Conductor Casing @ 370' 4' Pup Jt, 2 -7/8" 6.5# 1% Cr 8rd @ 7902' 2 -7/8" X Nipple (2.313" ID) 9 Cr @ 7906' 4' Pup Jt, 2 -7/8" 6.5# 1% Cr 8rd @ 7907' 1 jt 2 -7/8" 6.5# L80 +1 % Cr 8RD EUE Surf Csg: 10 3/4 ", 40.5 #, J55. 6' Pup Jt, 2 -7/8" 6.5# 1% Cr 8rd @ 7942' Set @ 1830', Cmt w/ 1300 sx. 7" TIW HM -1 Ret Pkr (13 Cr) @ 7948' 3 jts 2 -7/8" 6.5# L80 +1% Cr 8RD EUE 6' Pup Jt, 2 -7/8" 6.5# 1% Cr 8rd @ 8054' 2 -7/8" XN Nipple (2.205" ID) 9Cr @ 8060' 6' Pup Jt, 2 -7/8" 6.5# 1% Cr 8rd @ 8061' 7" x 2 -7/8" TIW OS GS @ 8067' Lower Completion Installed 8-4 -72 3 -' /z" Tbg stub top @ 8078' Otis 'X' Nipple (2.75" ID) @ 8981' Otis 'Q' Nipple (2.635" ID) @ 8992' r 1 • • i • ■ el f Guiberson RH -1 pkr @ 8081' KBG Mandrel #1 @ 8233' � GN-GO: 8108'-8140' Otis `XO' SS @ 8268' (closed) - ...I' Collapsed Csg 8120 -30'. Repaired w/ csg roller in IPM 1■001 1972 before running isolation packers. Guiberson RH -1 pkr @ 8272' — GR -GS: ' ' ® HC -HD: 8702 -8709 KBG Mandrel #2 @ 8759' (dummy) / — HC -HD: 8720' -8758' Otis'XO' SS @ 8795' (Open) HD -HE: 8766' -8775' Guiberson RH -1 pkr @ 8799' 11010■ Mandrel #3 @ 8857' (dummy) , - HE -HF: 8824' -8865' Otis `XO' SS @ 8892' (Open) moomm• Tbg Punch @ 8910-20' Guiberson RH -1 pkr @ 8896' / KBG Mandrel #4 @ 8932' (dummy) HI -HK: 8928' -8942 Otis'XO' SS @ 8967' (closed) HI -HK: 8955-8967' Guiberson RH-1 pkr @ 8970' "� N p.:1 Longstring: 7" N80 BTC Set @ 9530'. HK -HN: 8985' -9110' 26 #: surf - 8070' & 29 #: 8070' - 9530'. HN -HR: 9128' -9185' Cmt w/ 960 sx. HN -HR: 9198' -9278' PBTD: 9441' � HR -HZ: 9312'-9333' TD: 9555' ! /! / /� �A HR -HZ: 9355' -9440' 0 • ACB 5 -6 -13 ;fi ENERGY Proposed Completion KB: 35' MGS C24 -23 WIW �� Water Depth: 73' MSL Cook Inlet, Alaska ■ Leg 4, Conductor 32 Completion API No.: 50- 733 -20145 4' Pup Jt, 2 -7/8" 6.5# 1% Cr 8rd @ 278' Spud: 11 -24 -68 � � 2 -7/8" X Nipple (2.313" ID) 9Cr @ 282' Sidetracked from C11 -26 %/ 4. 4' Pup Jt, 2 -7/8" 6.5# 1% Cr 8rd @ 283' 250 jts 2 -7/8" 6.5# L80 +1 % Cr 8RD EUE 24" Conductor Casing © 370' 4' Pup Jt, 2 -7/8" 6.5# 1% Cr 8rd @ 7881' 2 -7/8" X Nipple (2.313" ID) 9 Cr @ 7885' 4' Pup Jt, 2 -7/8" 6.5# 1% Cr 8rd @ 7886' 1 jt 2 -7/8" 6.5# L80+1% Cr 8RD EUE Surf Csg: 10 3/4 ", 40.5 #, J55. 6' Pup Jt, 2 -7/8" 6.5# 1% Cr 8rd @ 7886' Set @ 1830', Cmt w/ 1300 sx. 1 jt 2 -7/8" 6.5# L80+1% Cr 8RD EUE 7" TIW HM -1 Ret Pkr (13 Cr) @ 7923' 4 jts 2 -7/8" 6.5# L80 +1% Cr 8RD EUE 6' Pup Jt, 2 -7/8" 6.5# 1% Cr 8rd © 8054' 2 -7/8" XN Nipple (2.205" ID) 9Cr @ 8060' 6' Pup Jt, 2 -7/8" 6.5# 1% Cr 8rd @ 8061' 7" x 2 -7/8" TIW OS GS @ 8067' Lower Completion Installed 8-4 -72 3 -W Tbg stub top © 8078' Otis 'X' Nipple (2.75" ID) © 8981' Otis 'Q' Nipple (2.635" ID) @ 8992' iI oi ■ w ., „ .. . „, pm 0; 0 f Guiberson RH -1 pkr @ 8081' / � KBG Mandrel #1 @ 8233' �� I ' GN -GO: 8108' -8140' Otis 'XO' SS @ 8268' (closed) �- I' Collapsed Csg 8120 -30'. Repaired w/ csg roller in Guiberson RH -1 pkr @ 8272' �— ► / 1972 before runn iso p a G R -GS: 8413' -8466' ' % H C -H D: 8702' -8709' KBG Mandrel #2 @ 8759' (dummy) HC -HD: 8720'-8758' Otis'XO' SS @ 8795' (Open) / � �� HD -HE: 8766' -8775' Guiberson RH -1 pkr @ 8799' �// � - KBG Mandrel #3 @ 8857' (dummy) % ■ HE -HF: 8824' -8865' Otis 'XO' SS @ 8892' (Open) p .�mmm E Guiberson RH -1 pkr @ 8896' 4— Tbg Punch @ 8910 -20' KBG Mandrel #4 @ 8932' (dummy) pi- g o, HI -HK: 8928' -8942' Otis `XO' SS @ 8967' (closed) HI -HK: 8955' -8967' Guiberson RH -1 pkr @ 8970' -• ....e Longstring: 7" N80 BTC Set @ 9530'. HK-HN: 8985' -9110' 26 #: surf - 8070' & 29 #: 8070' - 9530'. _ HN -HR: 9128' -9185' Cmt w/ 960 sx. — HN -HR: 9198' -9278' PBTD: 9441' ‚ itt HR -HZ: 9312-9333' TD: 9555' HR -HZ: 9355' -9440' • • CAMERON XTO PLATFORM C Well 24 -23 Equipment Current Wellhead 7 -2 -12 Tree 2 -9116 API 5K Run with 2 -1118 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 77 R -27 gT.r Pneumatic R -27 _ j ' ! _ SSV I n -CT -7J — J 1 . o "`0)' . Tubing Head Adapter Type D 11 API 5K (#10 Clamp) Hub Bottom x 2 -9116 API 5000 Top R-53 Ring Gasket Bottom R -27 Ring gasket Top R -2T 8" 9' 1 .-.... . ,r =--- t ice •, ,, ` r e L .-lu a� 6I 5st Lowermost Casing Head Type D Compact t _. .' - 11" 3K (#9 Clamp) Hub x 11 API 5K ( #10 Clamp) Hub Top j R-53 MODIFIED Ring Gasket Bottom .' „ 2 -1116 API 5K R -53 Ring Gasket Top R -24 Ring Gasket 4' 2" Annulus Outlets are 2-1/16 API 5K , R -24 Ring Gasket I I � a ii j� ' * ., j ot ~ - � G ` \.r L i 2' 11" 1 ' -1116 API 3K 2' 1 " '� ■---M-- D ) ■ : IR -24 Ring Gasket V ',R53 MODIFIED , . ,1 • • e k CAMERON XTO PLATFORM C Well 24 -23 INJECTOR REPLACEMENT EQUIPMENT 2012 Well currently has a Cameron Type D Compact Wellhead Existing 7" Casing will be cut to allow removal of the D Compact Housing. A new Casing Housing will be installed, the 7" tied back and a new Tubing Spool installed. We will also replace the Tubing Hanger, Adapter and Tree *Equipment to be configured as shown Trees configured the same as existing equipment currently on Wells per photographs i , (L ' 4, e I t- o. . • _r4 4J A 1 ) L Replacement 2 -9/16 5000 Tree With 2 -1/16 5K Wing 2 -1/16 5000 Wing HWO Pressure Side to Injection emu f --- � 41-144 �:1: • Replacement Tubing Head Adapter �! 7-1/16 x 2 -9/16 Stainless Adapter t, TT Replacement Tubing Hanger PN UNKNOWN 7 x 2 -7/8 EUE 8rd Stainless l' —1 PN UNKNOWN • R 11 Replacement Tubing Spool + C nig AMERON N 11 "5K x 7 -1/16 5K Top � I f P , 1 I ! r ' Replacement Secondary Seal PN Unknown + I PN UNKNOWN NX Bottom Prep ' F s� Replacement Slips Replacement Casing Head • PN UNKNOWN PN UNKNOWN -� eiy, \ • • 5/23/2012 13.625 BOP Schematic.xls XTO - ENERGY KS Elevation Date: 5/23/2012 "Rig Floor" (/ Flow ____> Flow line Nipple 7 HydrII 13 5/8" 5m v 13 518" Sm Annular double ram preventer rrs IT f77 mum I _ I r Z L 135/8 5m Cameron Irk 1 =No■ Pipe rams 13 5/8" Sm Cameron 114---ft Blind Rams .41i. :T=M}---4rlj O c 1. B I ,$ I 11sa`L1 Silt -- 21l16" Kill Line 3 1/S "Choke Line to to it UI to 2 1/16" 1/8" 31/8" 5m 5m 5m Hydraulic Manual Manual Valve I Valves valve 13 5/8 5m riser 13 5/8 "55 l ui11/wiui yl Mud Cross with 31/8" outlets Page 1 III V • S Schwartz, Guy L (DOA) P77) l -JO From: Bridge, Alexander <Alexander_Bridge @xtoenergy.com> Sent: Wednesday, May 01, 2013 10:23 AM To: Regg, James B (DOA); Schwartz, Guy L (DOA); Wallace, Chris D (DOA) Cc: Griffith, Scott; Duggin, Greg Subject: XTO Energy - C24 -23 (1681070) Rate and Pressure Monitoring MAR 2013 AIO # 9.007 Attachments: C24 -23 Rate and Pressure Monitoring MAR 2013 WO #9.007).xlsx Jim, Guy, and Chris: Attached is the March 2013 injection rate and wellhead pressure monitoring report for the Middle Ground Shoal C24 -23 as required by Administrative Approval AIO No. 9.007. The well was shut in during March for workover operations. Guy, As per our conversation, we performed a tubing pressure test and pre - injection MIT on this well after installing the new completion. Both tests passed. We then put the well injection and pressure immediately began to build on the tubing x casing annulus. We will submit an application for sundry approval to pull the completion and replace the packer. Regards, Alec Bridge Operations Engineer XTO Energy — Western Divison 303- 397 -3608 (0), 720 -244 -9083 (C) • Page 1 of 2 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Thursday, February 21, 2013 2:02 PM To: 'Bridge, Alexander' Subject: RE: XTO MGS C24 -23 - procedure addition (PTD 168 -107) Alex, Procedure is approved as proposed below and will be amended to the sundry 312 -259. I will add this email to the well file. Guy Schwartz �� 2013 Senior Petroleum Engineer SCANNED AOGCC 793 -1226 (office) 444 -3433 (cell) From: Bridge, Alexander [mailto:Alexander Bridge@xtoenergy.corn} Sent: Thursday, February 21, 2013 12:36 PM To: Schwartz, Guy L (DOA) Subject: RE: XTO MGS C24 -23 - procedure addition Guy, We'll also need to move step 28 (packer fluid) to AFTER the pickling procedure. It won't do us much good if we pump the packer fluid before the acid. Thanks, Alec From: Bridge, Alexander Sent: Thursday, February 21, 2013 2:23 PM To: Guy Schwartz (guy.schwartz @alaska.gov) Subject: XTO MGS C24 -23 - procedure addition Guy, The original procedure that was included in the workover sundry for the C24 -23 (Sundry 312 -259) did not include performing a pickle acid job on the new injection tubing. We'd like to add a pickle acid job to the procedure. This job would occur between steps 30 and 31 in the procedure dated 07 -06 -12 that was submitted with the sundry. This procedure for this proposed pickle acid job is the same as the C41 -23LN and A33 -14 procedures, which were approved. Pickle acid procedure: RU BJ to the tubing to pump 1,000 gal 10% pickle acid. RU PTS tank. Put 1,000 lbs soda ash in PTS tank to neutralize acid returns. Pressure test lines to 2,000 psig. Establish circulation down the tubing with workover fluid. Pump 500 gal 10% pickle acid down tubing at 2 — 3 BPM and displace with workover fluid. Under - displace acid 500' from EOT. RU rig pump to TCA. Reverse circulate the acid to the PTS tank. Repeat with the remaining 500 gal pickle acid. Pump spent acid down disposal well MGS C44 -14RD SWD. RD BJ. Please let me if you approve of the addition to the procedure, and please contact me if you have any 2/21/2013 Page 2 of 2 • questions or concerns. Thanks, Alec Bridge Operations Engineer XTO Energy — Western Divison 303- 397 -3608 (0), 720- 244 -9083 (C) alexander bridge @xtoenergy.com 2/21/2013 Page 1 of 1 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Friday, February 15, 2013 2:33 PM To: 'Bridge, Alexander' Subject: RE: XTO MGS C24 -23 (PTD 168 -107) Alex, You have approval to change the lower section of the completion as we discussed. Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) ... 444 -3433 (cell) From: Bridge, Alexander [mailto:Alexander_Bridge@xtoenergy.com] Sent: Friday, February 15, 2013 2:25 PM To: Schwartz, Guy L (DOA) P� 0 9 201a Subject: XTO MGS C24 -23 (PTD 168 -107) SCANNED Guy, Per our conversation, our BHA for the new completion has changed slightly. We will not be running a SBR on the end of the tailpipe because the 3 -1/2" tubing stub on top of the top Guiberson packer broke off, so we have nothing to sting onto. We will instead run a guide shoe with a 6.059" OD (drift of 7" 29# casing) and an ID of 2.441 ". The rest of the completion will be installed as detailed in the procedure. Please let me know if you have any other questions. Thanks, Alec Bridge Operations Engineer XTO Energy — Western Divison 303 - 397 -3608 (0), 720 - 244 -9083 (C) alexander_bridge @xtoenergy.com 2/15/2013 • • , &(SCZ4 -Z3 Pth 166 (070 Regg, James B (DOA) From: Regg, James B (DOA) Sent: Wednesda , December 26, 2012 1:30 PM i� � I Z / 1 Z - Cc: DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (DOA) Subject: RE: XTO Energy ref Well C24 -23 - OA -MIT ref AIO 9_007 Thank you. We would try to do this when next out there for BOPE test. Jim Regg AOGCC 333 7th Ave, suite 100 SC APR 1 120Y Anchorage, AK 99501 907- 793 -1236 From: Phillips, Barney [mailto:Barney Phillips @xtoeneray.com] Sent: Wednesday, December 26, 2012 1 :15 PM To: Regg, James B (DOA) Cc: Grimaldi, Louis R (DOA); Brooks, Phoebe L (DOA) Subject: XTO Energy ref Well C24 -23 - OA -MIT ref AIO 9_007 Hello Jim, During our 180 day cycle tests with your Inspector, Lou Grimaldi on 12/22/2012, we had intended to perform a required OA / MIT on the surface casing for well # C24 -23 as per AIO 9.007 I believe we had a faulty gauge as when we opened up to a test manifold, the shown surface casing pressure dropped from 25 PSI to 0 rapidly. At the time of this occurrence, we suspected there might be an obstruction or plug that caused the quick bleed off and it was decided to postpone this test until it could be investigated. On 12/24/2012, a new gauge was installed, valves re- checked and we were able to apply and perform an OA / MIT surface casing test of 500 PSI as required. A completed MIT Form is attached with pressures listed & noted "self witnessed ". We do understand that this was not an AOGCC "witnessed" test and would like to invite one of your Inspectors at your convenience to Platform C for witnessing of an OA / MIT test for this well. At this time, the surface casing has been bled back to our production header system which has a back pressure of 65 PSI and that is the current pressure of the surface casing with the well still on injection. Thanks & regards, Barney Phillips 907 - 776 -5251 Platform C 907 - 776 -5241 Platform A 907 - 394 -2454 Mobile 1 0 • " STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.reciaealaska.gov; AOGCC.Insoectors(rDalaska.gov; phoebe.brooks@alaska.00v chris.wallace(Malaska.gov OPERATOR: XTO Energy ' e q /ZI Zt7 /I zi FIELD 1 UNIT / PAD: MGS Platform C DATE: 12/24/12 OPERATOR REP: Barney Phillips AOGCC REP: None - Self witnessed Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well C24 -23 ' Type Inj. W ' TVD ' 7,864' Tubing 3,400 3,400 3,400 3,400 Interval V P.T.D. 1681070 - Type test M Test psi ' 500 Casing 3,400 3,400 3,400 3,400 P/F P Notes: OA 0 530 ' 515 515 Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Wet Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing 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 0 = Other (describe in notes) W = Water D = Differential Temperature Test Form 10 -426 (Revised 11/2012) MIT MGS C 12 24 12.xls C24-23 (1681070) Rate and Pressure Monitoring Administrative Approval AIO No. 9.007 Injected [bbl] Surf Casing [psig] Annulus [psig] Injection [psig] Comments Hrs Down 11/1/2012 266 25 3,500 3,550 0 11/2/2012 226 25 3,500 3,550 0 11/3/2012 211 25 3,500 3,550 0 11/4/2012 226 25 3,500 3,550 0 11/5/2012 213 25 3,400 3,500 0 11/6/2012 225 25 3,400 3,500 0 11/7/2012 243 25 3,400 3,500 0 11/8/2012 283 30 3,450 3,500 0 11/9/2012 232 30 3,425 3,475 1 3 11/10/2012 1 6 25 850 900 24 11/11/2012 5 25 750 800 24 11/12/2012 2 20 750 760 24 11/13/2012 4 20 725 750 24 11/14/2012 0 20 700 725 24 11/15/2012 0 20 700 725 24 11/16/2012 1 0 20 675 700 24 11/17/2012 0 20 675 700 24 11/18/2012 0 20 650 700 24 11/19/2012 0 20 650 700 24 11/20/2012 0 20 650 700 24 11/21/2012 0 20 650 700 1 24 11/22/2012 83 20 650 650 10 11/23/2012 165 20 2,600 2,600 0 11/24/2012 182 20 2,650 2,700 0 11/25/2012 205 20 2,650 2,700 0 11/26/2012 166 20 2,500 2,500 0 11/27/2012 172 20 2,450 21500 3 11/28/2012 1 264 20 3,400 3,450 0 11/29/2012 249 20 3,425 3,500 0 11/30/2012 252 25 1 3,425 3,500 0 d 5,000 4,500 4,000 3,500 3,000 2,500 2,000 1,500 1,000 500 XTO Energy - C24-23 (1681070) Rate and Pressure Monitoring Administrative Approval AIO No. 9.007 500 450 400 q ea C 350 0 U d 300 d 3 250 N N CL 200 N 16 U 150 f6 3 100 Cl) 50 0 0 �ti �ti �ti �ti ^ti ^ry �ti �ti ^ti ^ti �ti ^ti N% 0 It y r 16 ¢I l Z- , rOC�Gr � � � T ry IGq !°.?'" TO c n'tepS / - z 3 , ENERGY VLF 1 41/ 6 v XT MGS C24-23 NC. EAST FLANK, COOK INLET, ALASKA REPAIR PRESS COMMUNICATION PROCEDURE WELL DATA: SURFACE CASING: 10 -3/4 ", 40.5 #, J55. Set @ 1,830'. Cmt w/ 1,300 sx. PRODUCTION CASING: 7 ", N -80, BTC. Set @ 9,530'. Cmt w/ 960 sx. Surf - 8,070': 26# 8,070 — 9,530': 29# PBTD: 9,441' UPPER COMPLETION: 255 jts 2 -7/8 ", 6.5 #, L80, 8 RD, EUE @ 8,081' (Installed 1991) X Nipple (2.313" ID) @ 355' X Nipple (2.313" ID @ 7948' Baker PBR Seal Bore @ 7981' w/ 33,150# shear 7" Baker FHL Retrievable Packer @ 8000' w/ 50,000# shear XN Nipple (2.205" ID) @ 8038' Baker SBR @ 8081'. Stung over 3' stub of 3 -1/2" tbg from lower completion LOWER COMPLETION: 3 -1/2 ", 9.3 #, N80, 8rd, EUE 8078 -8992' (Installed 1972) Guiberson RH -1 pkr @ 8081' KBG Mandrel #1 @ 8233' Otis AO' sliding sleeve @ 8268' (closed) Guiberson RH -1 pkr @ 8272' KBG Mandrel #2 @ 8759' (dummy) Otis AO' sliding sleeve @ 8795' (open) Guiberson RH -1 pkr @ 8799' KBG Mandrel #3 @ 8857' (dummy) Otis AO' sliding sleeve @ 8892' (open) Guiberson RH -1 pkr @ 8896' KBG Mandrel #4 @ 8932' (dummy) Otis `XO' sliding sleeve @ 8967' (closed) Guiberson RH -1 pkr @ 8970' Otis `X' Nipple (2.75" ID) @ 8981' Otis `Q' Nipple (2.635 "ID) @ 8992' PERFORATIONS: GN - GO: 8108 -8140 (SS Closed) GR — GS: 8413 -8466' SCANNED APR 0 8 2013 HC — HD: 8702 -8709' HC — HD: 8720 -8758' HD — HE: 8766 -8775' HE — HF: 8824 -8865' HI — HK: 8928 -8942' (SS Closed) HI — HK: 8955 -8967' (SS Closed) 10 -3 -12 C:\ Users\ vlferguson \AppData\Local\Microsoft \Windows \Temporary Internet Files\ Content.Outlook \GTCWFQ55\C24 -23 Repair TCA comm Procedure 10- 3- 12.docx • • 2 HK — HN: 8985 -9110' HN — HR: 9128 -9185' HN — HR: 9198 -9278' HR — HZ: 9312 -9333' HR — HZ: 9355 -9440' BHST: 170 Deg F BHP: 4500 psi (SI WHP = 750 psi) HOLE DEVIATION: Max 19 Deg f/ 3400 -3700' MD SMALLEST ID: XN Nipple @ 8038' (2.205" ID) CURRENT INJECTION: 200 BWIPD @ 3500 psi as of 7 -2 -12. OBJECTIVE: Replace parted tbg w/ fish, Perforate tbg across HI -HK (SS Closed), & Coil tbg acidize HI-HZ. NOTES: • AFE # 1200482 Sundry #312 -259 • Slickline fish consists of GLV pulling tool and 8000' of slickline. Slickline parted at surface. It is not known if fish is inside 2 -7/8" tbg or in the annulus as there is speculation that the tbg is parted between 4000 — 5000'. • Expect heavy scale in the tbg as the 1.7" gage ring unable to pass 1234'. • The entire D Compact Wellhead will be replaced which will require cutting & replacing the top 150' of 7" casing. • Need 11" x 13 -5/8" clamp adapter for BOP. Materials Rqd: • 5000 gal Acid System for CT operations to contain these additives: ➢ 10% HCL ➢ gpt Corrosion Inhibitor ➢ ppt Iron Reducing Agent ➢ 2 gpt Surfactant • 200 bbl Gel Pill (2 lbs/bbl FloZan + 3 gal Greencide) (Provided by MI) • 1,000 lbs Soda Ash (MI) • 75,000 lbs CaC12 (400 bbls 11.4 ppg mud) 180 lbs/bbl FIW (Save mud for C24 -26RD & C34 -26) • 60 gal EC1447WR Corrosion Inhibitor (Nalco) • 250 BBL PTS Flowback Tank 10 -3 -12 C:\ Users\ vlferguson \AppData\Local\Microsoft \Windows \Temporary Internet Files\ Content.Outlook \GTCWFQ55\C24 -23 Repair TCA comm Procedure 10- 3- 12.docx • • 3 PROCEDURE: 1. SI well 2 weeks prior to RU & bleed down. MIRU derrick. 2. Mix 400 bbl 11.4 ppg CaC12 mud. RU mud pumps to tubing. Open the tbg annulus. Circulate to kill well from ±4000- 5000'. Take wellbore fluids to disposal well and recover /maintain the 11.4 ppg Salt mud. 3. SD & monitor well for 60 minutes to make sure well is dead. 4. Notify the AOGCC 48 hrs prior to BOP test. Set BPV. ND WH. Set 11" 5K x 13 -5/8" clamp adapter. NU riser & BOP's. Pull BPV's & set 2 -way check valve. Ensure BOP has VPR pipe rams for 2 -7/8" tbg. Press test BOP's to 250 psi & 5000 psi. Send D Compact WH to OS for scrap. 5. MI 8200' 3 -1/2" 15.5# S135 DP & 9 ea 4 -3/4" DC's (Min 2.25" ID). 6. PU on tbg & measure hook weight. POOH & LD 2 -7/8" tbg while checking for NORM. Send tbg to onshore to be sold for scrap. NOTE if SL fish is stuck in tbg. 7. If tbg is parted, RIH w/ Rolling Dog OS or Series 150 (depending on last tbg POOH). Make attempts to recover fish. If unsuccessful, consider 5 -3/4" wash pipe w/ 2 -7/8" tbg cutter. 8. Contingency Plan If WL Fish is Above Tbq Part: a) MU rope spear BHA consisting of Center Prong Rope Spear & Stop Collar w/ Drain Sub, 1 Jt 3 -1/2" Drill Pipe, 4 -3/4" Daily Bumper Jar, 4 -3/4" Daily Oil Jar & 6 ea 4 -3/4" Drill Collars. b) RIH to top of parted tbg. Establish all string weights no less than 200' from top of tbg, or shallower if down weight is seen. Rotate to engage WL. POOH. c) Cont. w/ Step 7. 9. RIH w/ 3.25" spear w/ 4' extension to engage Baker PBR (3.25" ID) @ 7981'. Shear & release pkr w/ 50,000# over -pull minimum. Circ 20 bbl gel sweep. POOH w/ pkr & 81' of tailpipe assembly. 10. RIH w/ dress -off mill to dress off top of the 5' 3 -1/2" tbg stub. BHA to consist of mill, casing scraper for 29# & MAGTRAP. LIGHTLY tag up on tbg stub @ 8078'. Dress-off tbg stub as per instructed. Reverse circ 20 bbl gel sweep. RU SL. (Confirm ID of MAGTRAP for SL tool.) RIH w/ 1.75" tool to check that the ID of 3 -1/2" tbg stub is not collapsed @ 8078'. POOH w/ SL. POOH & LD BHA. 11. RIH w/ HOWCO 7" 26# pkr to test csg. Set pkr @ ± 8000'. 12. Pressure test casing to 2000 psi & observe for 30 min. Report any pressure loss to Midland. If necessary RIH w/ pkr & RBP and isolate leak. 13. POOH w/ pkr. LD DP except for 500'. 10 -3 -12 C:\ Users\ vlferguson \AppData\Local\Microsoft \Windows \Temporary Internet Files\ Content.Outlook \GTCWFQ55\C24 -23 Repair TCA comm Procedure 10- 3- 12.docx • • 4 Casing Cut for Csg Spool Removal: 14. MI 4 jts 7" 26# L80 BTC -M. 1 jt to have Guided Skirt welded by pin end (Olgnoonik). 15. RIH w/ HOWCO 7" 26# RBP & set @ 500'. Close pipe rams & press test to 1000 psi. POOH. Drop 500 lbs (20') of sand on top of RBP. 16. MU 7" casing cutter on DP. RIH & cut the 7" csg ±20' below the WH assembly. Circ out any gas. POOH & LD cutter. 17. ND BOP's. 18. Remove the bottom clamp from bottom of D Compact WH. LD WH w/ casing hanger & the 20' 7" casing stub. Lti (19. NU the new Cameron 11" 3K x 13 -5/8" 5K casing head. Weld landing hub to 10 -3/4" csg. +. 20. RIH w/ 4 -1/4" x 7 -3/8" TAM Inflatable Pkr as per Attached TAM Running Procedure to ±100'. Inflate & release from the pkr. POOH w/ DP. 21. NU 13 -5/8" 5K flange with connection for test port. RU line. A( 22. Press test the weld & new clamp on the bottom of the new Casing Head to 2000 psi for 30 min against the inflatable pkr. rfi 1 51- 23. ND the 13 -5/8" flange. RIH & deflate the pkr. POOH w/ pkr. 24. Notify the AOGCC 48 hrs prior to BOP test. NU BOP's w/ 7" casing rams. Press test BOP's to 250 psi & 5000 psi. 25. RIH w/ 5 -3/4" ITCO Spear w/ 2.0" ID and engage the top of 7" & PU 5000# over string wt. RU Pollard WL. RIH w/ string shot & CCL. Apply recommended torque to 7 ". Fire string shot in collar between 100 -150'. Backoff casing at collar. POOH & LD ±3 jts csg. 26. RU Casing Crew. PU Guided Skirt jt followed w/ 3 reg jts of 7" 26# L80 BTC -M. Slip skirt over the collar from previous step & MU threads. Screw on 7" swage w/ 1502 2" connection. RU mud pump and press test the new 7" connection against the RBP to 2000 psi for 30 min. Bleed -off press. RD BOP's. Hang off 7" on slips in WH, make cut and install new Cameron Tubing Spool. 27. Notify the AOGCC 48 hrs prior to BOP test. NU BOP's with VPR's for 2 -7/8 ". Set WH test plug in tbg spool. Press test BOP's to 250 psi & 5000 psi. 28. RIH and wash off sand & retrieve the 7" RBP @ 500'. POOH & LD DP. 29. MI 8350' 2 -7/8" 6.5# L80 + 1% Cr 8rd EUE tbg (incl 3% excess). 30. RIH w/ 7" Chrome Retrievable Pkr as follows: 10 -3 -12 C:\ UsersW lferguson \AppData\Local\Microsoft \Windows \Temporary Internet Files\ Content.Outlook \GTCWFQ55\C24 -23 Repair TCA comm Procedure 10- 3- 12.docx • • 5 Item Length, ft Top Bottom 2 -7/8" 6.5# L80 + 1% Cr 8rd EUE 300 0 300 4' Pup Jt, 2 -7/8" 6.5# 1% Cr 8rd EUE 4 300 304 2 -7/8" X Nipple (2.313" ID) 9 Cr 1 304 305 4' Pup Jt, 2 -7/8" 6.5# 1% Cr 8rd EUE 4 305 309 2 -7/8" 6.5# L80 + 1% Cr 8rd EUE 7,616 309 7,925 4' Pup Jt, 2 -7/8" 6.5# 1% Cr 8rd EUE 4 7,925 7,929 2 -7/8" X Nipple (2.313" ID) 9 Cr 1 7,929 7,930 4' Pup Jt, 2 -7/8" 6.5# 1% Cr 8rd EUE 4 7,930 7,934 1 jt 2 -7/8" 6.5# L80 1% Cr 8rd EUE 31 7,934 7,965 7" TIW HM -1 Retrievable Packer (13 Cr) 4 7,965 7,969 3 jts 2 -7/8" 6.5# L80 1% Cr 8rd EUE 93 7,969 8,062 6' Pup Jt, 2 -7/8" 6.5# 1% Cr 8rd EUE 6 8,062 8,068 2 -7/8" XN Nipple (2.205" ID) 9 Cr 1 8,068 8,069 6' Pup Jt, 2 -7/8" 6.5# 1% Cr 8rd EUE 6 8,069 8,075 3 -1/2" x 2 -7/8" TIW SBR (13 Cr) Stabbed in @ 8081' 6 8,075 8,081 * Space out then leave 1 jt out to pump pkr fluid. 31. Prior to setting the packer, circ 260 bbl packer fluid @ 4 BPM containing 60 gal Nalco EC 1447WR in 260 bbl FIW. 32. PU landing jt & stab 3 -1/2" SBR onto 3 -1/2" tbg stub at 8078'. 33. Space out & make up and land new SS Tbg Hanger. Run in lock screws to energize hanger seal. 34. RU Slick line & press test lubricator to 4,000 psi. RIH w/ ±1.75" (verify diameter from Step #10) tool to 8200' to verify the SBR is stabbed onto 3 -1/2" tbg sub @ 8081'. 35. RIH w/ PXN plug & set in XN nipple @ 8,068'. Press test tbg to 1,000 psi for 15 min. Monitor falloff. Cont to press up to ±3,500 psi to set pkr. Hold 4,000 psi on the tbg for 15 min. POOH w/ SL. 36. Perform the MIT on the 2 -7/8" tbg annulus w/ a chart recorder. With the 7" Packer set @ 7965' MD, press test the tbg annulus to 2000 psi. (7840' TVD x 0.25 = 1960 psi) and hold for 30 minutes. 37. Set BPV. ND BOP's. NU WH w/ new SS tbg head adapter. Pull BPV. Set 2 -way check. Test WH to 5,000 psi. Pull 2-way check. 38. RU SL. RIH & pull the PXN plug. RD SL. Rel derrick. 39. Install SSV on wellhead as per AOGCC. 10 -3 -12 C:\ Users\ vlferguson \AppData\Local\Microsoft \Windows \Temporary Internet Files \Content.Outlook \GTCWFQ55\C24 -23 Repair TCA comm Procedure 10- 3- 12.docx • • 6 Coil Tbg Operation (Work to be done at a later date & Req Separate Sundry): 1. MIRU BJ 1.75" Coil Tbg Unit. RU a filter skid between the mud pits & HP triplex. Install press gauges on the CT, CT Annulus & 2 -7/8" tbg annulus. Make up 1- 11/16" mud motor w/ 2.0" drag bit & circ sub. Contact the AOGCC 48 hrs prior to BOP test. Press test all lines & BOP's to 5,000 psi. MAX Press = 4,000 psi & MAX Fluid Rate for motor = 1.0 BPM. CTU operator to ensure all tools to be calipered before RIH. Smallest ID = 2.205" XN Nipple @ 8068'. 2. Open the CT annulus. RIH w/ CT @ 80 fpm while pumping slick FIW @ 0.5 BPM to 8000'. 3. Slow coil speed to ±10 fpm when approaching 3 -1/2" tbg stub @ 8078'. Once past 8100', cont DH at ± 25 ft/min to PBTD @ 9441'. 4. Drop ball & open circ sub. Pump bottoms up w/ 20 bbls gel pill & 50 FIW @ 1.5 BPM. 5. POOH. LD motor /mill BHA. Move Injection Head aside. 6. RU WL. Install lubricator & press test to 2000 psi. MU 10' tbg punch gun w/ 2 spf. RIH w/ CCL & tbg punch gun. Correlate to Dresser Atlas CCL 10- 13 -83. Fire gun @ 8910 -20' (HI -HK). POOH. RD WL. 7. RU CT Inj Head & press test to 5000 psi. MU jet wash tool on CT. RIH @ 80 fpm to 8000' while circulating 1 /2 BPM regular FIW. Slow to 10 ft/min from 8000 - 8100'. Cont DH to 9440' @ 25 ft/min. 8. Lay 700 gal (16.6 bbl) 10% HCL @ 1 BPM in the 7" csg from 9440' to 8992' while PUH @ 27 fpm. Cont to lay 300 gal (7 bbl) acid in the 3 -1/2" tbg from 8992 to ±8200' while PUH @ 57 fpm while pumping 1 /2 BPM. Displace w/ FIW. PU CT to 8000' & SD. Let acid soak for 30 min. 9. RIH to 9440' @ 30 fpm & 1.5 BPM while circ out acid with 70 bbl FIW. 10. SI the CT annulus. Sqz 4000 gal acid as follows: • 7" Casing: Pump 2100 gal (50 bbl) 10% HCL while making 3 passes across 9440 - 9000' while pumping @ 0.7 BPM and moving the CT @ 20 ft/min. • 3 -1/2" tbg: Pump 1700 gal (40 bbl) 10% HCL while making 3 passes across 8970 - 8780' while pumping @ 0.7 BPM and moving the CT @ 10 ft/min. 11. Over flush acid with 100 bbl FIW while making 2 passes across the interval from 8780 — 9440' while pumping @ 0.7 BPM and moving the CT @ 10 ft/min. 12. Open CT annulus. P0011 @100 fpm. Close swab valve. RD CTU. RWTI. Paul Figel Engineering Manager 10 -3 -12 C:\ Users\ vlferguson \AppData\Loeal\Microsoft \Windows \Temporary Internet Files\ Content.Outlook \GTCWFQ55\C24 -23 Repair TCA comm Procedure 10- 3- 12.docx • • TAM INTERNATIONAL Inflatable Packers Single Set Packer Running Procedure rev.00 OBJECTIVE: Run 4 %4" X 7 3/8" Single Set Packer through 8 7/8" wellhead restriction and set inside 10 3 /4" casing to test welded landing hub of the wellhead. EQUIPMENT: 03501B0288EPP10:Crossover Sub, 3 IF box X 2 7/8" EU pin, P110 PJ0288L8OEUE4: 4' Pup Joint, L80, 2 7/8" EU box X pin 500- CN -03: 5.00" TAMCON ON /OFF Tool, with (500- CN-45) Fishing Neck Sub Assembly installed, 8 1/4" OD Bell Guide installed (500- CN -17), 2 7/8" EU box X pin, (No shear Pins) Max tensile: 69,200 lbs Max torque: 2880 ft-lbs 425- SS -05: 4 1/4" X 7 3/8" Single Set Packer, 738 -VE -11 element exposed slats down, set sleeve shear pinned 1125 psi (3 pins), choke (425- TJ-41) for 15/16" ball shear pinned at 2250 psi (5 pins), Solid Guide Plug (425- PW -76) down with 7.44" OD Gage Ring (525- RW -29), 2 7/8" EU box up, Circulation Ports open, Equalization Ports open, rotate release Maximum Element Working Pressure in 10.05" ID casing is 3500 psi from above and 491 psi from below Complete Backup Tool String As Described Above PRE -JOB PROCEDURE: 425 -SS -05 PESI Alaska Running Procedure rev.00 9 -28 -12 gs - 1 - A. Upon rig arrival at the ri site, immediately•ck all tools on location against the shipping documents and check the tools' condition to assure that no damage has occurred during transportation to the rig site. B. Insure that all TAM equipment is compatible with other equipment on location and that all required handling tools are on location. C. Discuss job procedure with company personnel and all other involved personnel. D. Complete JSA form. E. Confirm fluid type and fluid level of the well. F. Verify if Loss Circulation Material (LCM) is in the well fluid, if so, clean well fluid will need to be spotted across the Packer for inflation of the Packer, to prevent plugging of the inflation ports. G. Caliper and drift all crossovers, nipples, tubing, etc. with 15/16" setting ball to ensure ball will pass through all ID's. Drift work string with appropriate size drift. H. Lightly dope pin end only on workstring. I. Verify workstring is clean and free of debris. J. The following operating procedures should be followed for running and activating the Packer Assembly. I I RUNNING PROCEDURE: 425 -SS -05 PESI Alaska Running Procedure rev.00 9 -28 -12 gs - 2 - 1. Make p on the workstring: Crossover, Pup Joint, TAMCON (500- CN -03), and Single Set Packer (425- SS -05). 2. Run in hole at a moderate speed. Make sure to slow down and take caution while passing through any restrictions. I 3. Prior to reaching the setting depth at approximately 100 feet, establish neutral, up and down weights and record. 4. Test surface lines to 4000 psi or safe operating practices. 5. Pump a minimum of 10 bbls. fluid down the workstring to ensure the Choke Seat is clean and free of debris. 6. Caliper and drop 15/16" setting Ball down the workstring. Allow for the Ball to fall to the Choke Seat. 7. Slowly increase pressure down the work string to 500 psi to start inflating the Bridge Plug and hold for 5 minutes. 8. Pick up 2 — 3000 lbs. above recorded up weight to confirm the Bridge Plug is inflating. Slack off to neutral weight. Note: Be careful not to let workstring rotate before the setting process is complete. 9. Slowly increase pressure to 900 psi and hold for 5 minutes. 10. Increase pressure to 1125 psi (+ 20 %) to shear the Set Sleeve and lock pressure in the Element. 11. Release pressure to 0 psi. 12. Pick up 2 — 3000 lbs. over established string weight to verify the element is inflated and locked set. Monitor for 5 min. 13. Shut in drillpipe at surface. Pressure test casing down annulus between drillpipe and casing to 2000 psi. (Max working pressure is 3500 psi above packer) Note: 2 -3000 lbs of tension must be left on drillpipe during pressure testing of casing. 14. When pressure test is complete per customer requirements, bleed Lines to 0 psi. RETRIEVING PROCEDURE: 15. Slowly increase pressure down drillpipe in 500 psi increments to 425 -SS -05 PESI Alaska Running Procedure rev.00 9 -28 -12 gs - 3 - • 2250 psi to shear the Choke. A pressure loss should be seen. 16. Pull slight tension on workstring. Rotate workstring 8 turns to the right to deflate the Packer. Note: Do not rotate more than 8 turns at the Packer. This could cause damage to the Packer and potentially drop the Packer downhole. Monitor the Weight Indicator to verify the weight is dropping indicating the Element is deflating. 17. Wait 15 minutes for the Element to completely deflate and pull out of the hole with the Packer. CONTENGENCY: Should it become necessary to release from the Packer; • Slack off string weight on the Packer. Rotate the workstring % turn to the left. While holding 1 /4 left hand turn, pick up 5' to confirm release from the Packer. Note: Torque in the wrench should be relieved as the lug on the fishing neck sub assembly moves through the groove in the TAMCON overshot confirming release from the Packer. 425 -SS -05 PESI Alaska Running Procedure rev.00 9 -28 -12 gs - 4 - . . (,J L L WJL / SEANPARNELL GOVERNOR AISA SKA OIL AND GA,r! 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. .- 200 N. Loraine, Suite 800 Midland, TX 79701 Re: Middle Ground Shoal Field, E, F, & G Oil Pool, MGS #C24 -23 Sundry Number: 312 -259 � r Dear Ms. Perez: �� 0 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, Daniel T. Seamount, Jr. Commissioner DATED this 2-R day of August, 2012. Encl. i • RECEIVED JUL 16 2012 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 #C24 -23 Water Injection Well Middle Ground Shoal Field, E, F, & G Oil Pool Cook Inlet, Alaska API 50-733-20145-01-00 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. Rate & Pressure Monitoring Plots for Injection Waiver. 5. Deviation Survey. 6. Job Procedure. 7. Current Wellbore Diagram. 8. Proposed Wellbore Diagram. 9. Wellhead Schematic. 10. 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 t 0 I/4 RECEIVED STATE OF ALASKA JUL 1 6 2012 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well 0 Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate ID _ Pull Tubing 0 Time Extension ❑ Operations Shutdown ❑ Re -enter Susp. Well ❑ Stimulate • Alter Casing 0 Other: ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: XTO Energy Inc. Development ❑ Exploratory ❑ 168 -107 ' 3. Address: Stratigraphic ❑ Service El 6. API Number: 200 N. Loraine, Suite 800, Midland, Texas 79701 50- 733 - 20145 -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 0 Middle Ground Shoal #C24 -23 • 9. Property Designation (Lease Number): 10. Field / Pool(s): ADL 18756 • MGS E, F, & G Oil Pools' 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): 9555' . 9407' 9441' NA NA Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 1830 10 -3/4" 1830' 1812' 3130 psi 1580 psi Intermediate Production 9530 7" 9530' 9383' 7240 psi 5410 psi Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 8108' -9440' 7973' -9294' 2 -7/8" & 3 -1/2" L -80, N80 8081' & 8992' Packers and SSSV Type: Baker FHL + 5 ea Guiberson RH1 Packers and SSSV MD (ft) and TVD (ft): See Attachment 12. Attachments: Description Summary of Proposal El 13. Well Class after proposed work: Detailed Operations Program El BOP Sketch El Exploratory ❑ Development ❑ Service El • 14. Estimated Date for 10/1/2012 15. Well Status after proposed work: Commencing Operations: Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: WINJ El • 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 t-eA'{ COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 31 2 - 25 Plug Integrity ❑ BOP Test Mechanical Integrity Test 'RI Location Clearance ❑ w`r L,.L er A C v[ Other: f� � � *0 oo0p 5 cf.cr.I) r� red C�' J o D JG'i" `z f / dri / v AC° c/ c rat c e w • • � �� 9 Svr t- scs F t v h/e rctd per O A. C ,25,2 b Subsequent Form Required: Al 17-,t ✓✓ re et Uilea /e - 4O tf APPROVED BY / �� Approved b � � COMMISSIONER THE COMMISSION Date: Z, ��I / / F� s�d �/ V t ,t- r Submit in Du licate N �.++D�r�v�'''cc..aa A X112 g ORIGINAL 4,- 8 J • • Application For Sundry Approval Attachment to Form 10 -403 Packers and SSSV MD (ft) and TVD (ft): MD TVD Pkr 8000' 7838' Pkr 8081' 7945' Pkr 8272' 8141' Pkr 8799' 8655' Pkr 8896' 8752' Pkr 8970' 8825' • TG ENERGY July 2, 2012 To: John Norman Victoria Ferguson Cc: Scott Griffith Scott Landon From: Paul Figel Subject: Workover for MGS C24 -23 (168 -107): Repair Tubing Pressure Communication Objective: The workover proposed for the C24 -23, located on Platform C, Cook Inlet, is to repair the pressure communication on the tubing by casing annulus. The AOGCC granted the first Injection Waiver in 2006 but revised the waiver in 2010 that mandated the installation of pressure relief valves. The current completion has 5 each 1972 Guiberson packers with sliding sleeves isolating the major intervals that will remain in place while a new packer will replace the 1991 uppermost Baker packer. The isolated tubing between the HI -HK will be perforated to allow flood support. The well is scaled up according the last slickline run in 2005 where the tool was unable to pass 1200'. Therefore, after the new replacement tubing has been run and tied back to the original straddle packer completion, coil tubing will be utilized to clean out and acidize the bottom section. This well is currently equipped with an outdated product (Type D Uni- Compact Head) that Cameron no longer supports nor has adapter parts to allow for a new tubing hanger to be installed. Therefore, the entire existing wellhead will be removed and replaced with a conventional multi - compartment wellhead. This will be done as outlined in the procedure requiring that the 7" Longstring be cut below the deck to allow the removal of the lowermost casing head section. Approximately 150' of the 7" casing will be replaced and brought back to surface and hung off in a new casing head with slips. This will allow a new tubing spool to be installed. Well History: The C24 -23 was drilled in 1968 in the East Flank Hemlock. It IP'd at 826 BOPD and was converted to injection in 1969 with a 2700 BPD rate. In 1972, 5 straddle packers were installed to regulate the water injection as the HI -HK interval was taking over 50% of the water. The well was put on injection at 4700 BPD with the sleeves open to the GR -HE, HE -HF & HK -HZ. The last major workover was performed in 1991 to repair pressure communication. The objective to pull the 5 packers was cancelled due to encountering tight casing at 8049'. Therefore, a 6th packer with a sealbore receptacle was stabbed onto the tubing fish as a secondary option to return the well to injection. There were 4 coil tubing acid cleanouts from 1982 -1991. In 1992, 8000' of slickline parted while conducting operations. The operator had speculated that the tubing was parted between 4000 — 5000 ft that caused the failure but this has not been verified. The current injection rate is 200 BPD. • 2 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, Pe r. Paul Figel Engineering Manager MGS (E) C24 -23 (INJ) 10000 1 MIDDLE GROUND SHOAL EFG 5000 vm • 1000 500 I 100 _ • 50 - M3S (E) 024-23 (III co al CDwr • 10 - CD Gas -9 -t CD VAtrInj 5 CD InjFTess Test BOFD Alaska O Test B1AFD Alaska Test NCFFD Alaska 1 196869 70 71 72 73 74 75 76 77 78 79 80 81 82 83 84 85 86 87 88 89 90 91 92 93 94 95 96 97 98 99?00031 02 03 04 05 06 07 08 09 10 11 12 Cum Oil 83495.000 Date L XTO Energy - C24 -23 (1681070) Rate and Pressure Monitoring Administrative Approval AIO No. 9.007 5,000 ■Iii■CsgxTbg Annulus Pressure 500 ■•U Injection Pressure 4,500 Injection Rate (bbl /d) 450 .40.-- Surface Casing Pressure • 4,000 400 a) 0 IY d CL 3,500 350 0 c Vie f) 0 a) 3,000 300 c a) •� otS a) 05 2,500 250 = N = N _ 7 a) L c 2,000 200 a c Q c H 1,500 150 U x rn c • N 100 `t U 1,000 cn 500 50 0 • I • I • I • I • I • I • I I • I • I • I • I • I • I • I 0 O�� O 0 O 0 O 0 O 0 O 0 O 0 O O� O O�� 9. O�� 9 O O� h \ ^ \` + 3 " h \ � ' 4. h AO h \ C y \'� \ � y \N y \'� h \'� \ � h \N �' \ � y \`L \ � h \` h \` \ � \ `L � \ � \ �L ° ' \ � N h \ 'b � \ry 1 I CsgxTbg Annulus & Injection Pressure o o ° O o 0 0 ° O ° ° O o 1/1/2011 ' f , if 1 2/1/2011 311/2011 u) 5 5 0 41, X (U n n ` X N O O 6 4/1/2011 - '• v 53 `° 0 j ( D fn 7 5/1/2011 11 ETE co aD cn ( '-111111 FO cn 6/1/2011 INW— - 7/1/2011 • • • lw �� --• N 8/1/2011 I-1- c") . I. si) ----. a) 9/1/2011 -- CD CO Do 10/1/2011 -0 ."%1 -Z O O 1111/2011 _ - ,�, x < 2) I - ANY a ` 1 111111411 12/1/2011 ,�,/e > CO 0 Q 1/1/2012 — _�, � Z -- O cD 2/1/2012 _ U ) y CD 3/1/2012 4/1/2012 Marva. O • -- O 5/1/2012 — - .r CO 6/1/2012 - 1 1 I N N W W A O 0 0 al 0 al 0 al 0 al O 0 O O O O O O Surface Casing Pressure & Injection Rate • 410 ' . • DIRECTIONAL INFORMATION PLATFORM C PROD LEG 4 CUND 32 C24 -23 MIDDLE GROUND SHOAL FIELD 8107187 SHELL- CSTA8- NDARD X4-23 145.0 -4775 -1543 4 1 METHOD SELECTED IS NUMBER 4 UNITS OF OUTPUT CONFORM INPUT (RADIUS OF CURVATURE APPROACH) DOGLEG IN DEGREES PER i• s UNITS SURVEY DATA DATA DERIVED FROM MEASUREMENTS MEASURED DEVIATION VERTICAL LATERAL DEFLECTION DOG SURVEY POINT DEPTH DRIFT DRIFT DEPTH FROM SURFACE LOCATION LEG COORDINATES (DDF) ANGLE DIRECTION (BDF) N OR St -1 E OR Wt -i Y X 0 00 N 0 E 0.0 0.0 0.0 0.0 - 4775.8 - 1543.0 140 0 15 N 64 E 1 =.0 0.2 0.1 0.3 - 4774.8 - 1542.9 200 0 0 N •0 E 200.6 0.4 0.2 0.3 - 4774.6 - 1542.8 300 0 15 N 74 E 300.0 0.5 0.3 0.3 - 4774.5 - 1542.7 400 0 0 N 0 E 405.0 0.7 0.5 0.3 - 4774.3 - 1542.5 500 3 0 N 80 W 5 2.5 -1.1 3.7 - 4772.5 - 1544.f 600 6 15 N 87 W 599.6 3.4 -9.1 3.3 - 4771.6 • - 1552.1 740 7 15 S 64 W 698.9 1,1 -20.5 3.6 - 4773.9 - 1563.5 ' 800 6 6 S 39 W 798.2 -6.0 -29.5 3.1 - 4781.0 - 1572.5 • 900 6 30 S 54 W 897.7 -13.5 -37.3 1.7 - 4788.5 - 1584.3 • 1000 8 45 S 63 W 996.8 -20.4 ' -48.6 2.5 - 4795.4 - 1591.6 1100 # 0 30 S 69 W 1095.4 -27.2 -63.9 2.0 - 4802.2 - 1606.9 1200 12 0 S 74 W 1193.4 -33.4 -82.4 1.8 - 4808.4 - 1625.4 1300 10 45 S 61 W 1291.5 -40.9 -100.6 2.9 - 4815.9 - 1643.6 1400 10 0 S 50 W 1389.8 -51.1 -115.4 2.1 - 4826.1 -1658.4 4500 8 30 S 40 W 4488.5 -62.5 -126.7 2.2 - 4837.5 - 1669.7 _ - 1600 10 15 S 44 W 1587.2 -74.6 -137.6 1.9 - 4849.6 - 1680.6 4700• 12 45 S 54 W 1685.2 -88.0 -152.3 2.9 - 4863.0 - 1695.3 1800 13 30 S 54 W 4782.6 -104.8 -170.3 1.0 - 4876.8 - 1713.3 1900 13 30 S 56 W 1879.8 -115.2 -189.5 0.5 - 4890.2 - 1732.5 2000 13 45 S 56 W 1977.0 -128.4 -209.0 0.3 - 4903.4 - 1752.E 2100 13 30 S 58 W 2074.2 -441.2 -228.7 0.5 - 4946.2 - 1771.7 2200 43 45 S 57 W 2171.3 -153.9 -248.6 0.3 - 4928.9 - 1791.6 2360 13 i5 S 62 V 2268.4 -165.7 -268.7 1.3 - 4940.7 - 1811.7 • 2406 43 0 S 61 U 2366.0 -176.6 -288.7 9.3 - 4951.6 - 1831.7 2500 13 30 S 64 W 2463.3 -187.1 -309.6 0,9 - 4962.1 - 1852.0 2600 13 30 S 65 W 2560.5 -497.2 -330.1 0.2 - 4972.2 - 1873.1 2704 14 0 S 65 W 2657.7 -207.2 -351.6 0.5 - 4982.2 - 1894.6 2803 14 15 S 67 W 2754.7 -217.2 -373.9 0.5 - 4992.2 - 1916.9 2900 15 0 S 68 W 2851.4 -226.8 -397.2 0.8 - 5001.8 - 1949.2 3006 16 0 S 70 W 2947.8 -236.4 -422.2 1.1 - 5841.4 - 1965.2 3108 16 30 S 75 W 3051.5 -245.5 -451.0 1.4 - 5026.5 - 1994.0 3265 17 45 S 78 W 3201.5 -256.3 -475.9 1.0 - 5031.3 - 2038.9 3418 19 0 S 80 U 3346.7 -265.5 -543.3 0.9 - 5040.5 - 2086.3 3578 19 15 S 85 W 3497.9 -272.3 -595.2 1.0 - 5047.3 - 2138.2 3640 19 15 S 78 W 3556.4 -275.3 -615.4 3.7 - 5050.3 - 2158.4 3687 18 45 S 74 W 3600.8 -279.0 -630.3 3.0 - 5054.0 - 2173.3 373? 16 0 S 86 W 3650.5 -281.7 - 645.6 8,7 - 5056.7 - 2188.6 3830 15 15 S 87 W 3738.1 -283.2 -670.0 0.9 - 5058.2 - 2213.0 3987 13 30 S 85 id 3890.2 -285.9 -708.9 4.2 - 5060.9 - 2251.9 4141 12 15 S 839 W 4040.3 -287.7 -743.2 1.0 - 5062.7 - 2256.2 4295 10 45 N 88 W 4191.2 -287.5 -773.9 1.0 - 5062.5 - 2316.9 4455 10 0 N 90 W 4348.6 -287.0 -..2.7 0.5 - 5062.0 - 2345.7 4581 9 0 N 8814 4472.9 -286.6 -823.5 0.8 - 5061.6 - 2366.5 A770 0 78 N 07 U AL O A -7R5 A -OA7 Z A 1 -SALA A - 1706 7 • • £'9 6'44L4- Z'4 £'£1£1- l'9£ L'9446 A 61 N 54 9 SSS6 -- 8'1584- 9'LzL4- Z'4 8'84£1- FL; -3'86 "c6 A 4Z N 9E 9 8E46 6'4482- S'SLL4- 1'1 6'14£1- S'9- 5'8116 NI ZZ N St 9 S9Z6 9'Z48Z- L'98L4- £'9 9'6621- L'S- 8'S9O6 A LZ N 9 9 ZIZ6 8'L €8Z- 9'9614 £'4 8'46ZI- 4'51- 4'8968 A LZ N Sl 9 4116 I'££8Z- Z'66L4- 4'4 I'46Z1- Z'4Z- 9'2188 A 1Z N 4 9 - L196 • £'6ZSZ- £'9684- 1'1 £'9821 4'1£ 4'96L8 A 6Z N 51 9 1468. • • 5'5282- 2'£184- 9'9 - S'Z8ZI- Z'8£- 'BZLB A OE N 0 _t £L88 8'4ZBZ- £'IZ84- 8'4 8'LLZ1- £'94- 41598 A 4£ N 9 L 96L8 . 8'Z18Z- k'££84- 6'9 8'6921- 4'8S- £`9£58 A L£ N SI L 6L98 9'66LZ- • £'2584- 2'4 9'9521- £'LL- 4'9L£8 A S£ N 54 8 1IS8 £'48LZ- 6'ZL84- £'4 £'14Z1- 6'16- 6'ZOZ8 A 9E N $£ 8 24£8 . V'89/Z- 41684- 8'9 4'5221- 4'611- B'4Z48 A 8E N 4 8 6518 Z'9SLZ- 6'L06t- £'9 Z'£Ic'1- 6'2£1- ' 1188L A S4 N 9£ L IZ48 £'£4LZ- L'RZ64- 4'4 £'49Z1- L'S4l- Z'ZWLL A S4 N 9 L L18L L't£LZ- £7.£64- £'4 L'881I- £'L51- Z'£49L A 54 N 4£ 9 L£LL £'BILZ- 5'5464- Z'4 £'SL11- S'9LI- Z'Z£4L N 94 N 4 9 595E 9'84L2- Z'S564- 4'9 9'5911- Z'OBI- 6'96ZL A 84 N 9 9 6ZiL L'L69Z- L'£964- 4'4 L'45I1- L'881- L'ZLIL A ZE N S1 9 44£L S'9B9Z- S'ZL64- 9'4 5'£411- S'L61- 5'L49L A ZS N 54 9 BL IL I'SL9Z- 8'4864- 9'1 1'Z£11- B'SeZ- E'Z£69 A 9S N Si L 299L S'499Z- I'L864- £'9 S' 1211- I'ZIZ- 17£89 A £9 N 54 9 1969 4'£492- I'L664- 8'4 4'44II- 1'ZZZ- F Z99 A 99 N 51 9 5549 FLEW- 1'9445- Z'9 £'4641- l'SZZ- 8'£959 A 29 N 0 9 1699 4'4Z9Z- - £'8445- 4'4 4'L1e!- £'££Z- 8'48£9 A 99 N 4 9 1IS9 Z'L192- L'6445- £'4 Z'4L01- L'4EZ- 4'25£9 A 99 N 9 9 BL49 1'899Z- 6'£145- £'4 1'5981- 6'BEZ- S'BSZ9 A 59 N 51 9 48£9 9'LBSZ- 9'ZZ95- 5'9 9'4441- 9'L4Z- 8'2999 N1 69 N S4 9 L819 1'4LS2- ;WAS- 9'4 1'1E01- I'ZSZ- 9'Z46S A 4L N 54 9 9999 l'6SSZ- 4'1£95- 4'9 1'9141- 4'95Z- 9'LI85 A 4L N 4£ L 4465 6'StSZ- S'S£45- 4'4 6'Z99I- 5'492- S'41L5 A ZL N 54 L 9ESS L'SZSZ- 1' 1495- 4'9 L'Z86- 1'99Z- 6'LSSS A LL N 9£ L 8L9S 1'6452- 61495- S'4 1'996- 6'69Z- I'EE45 A LL II 9 8 ZSSS I'L84Z- 4.`9595- 5'9 1146- 9'SLZ- L'6LZ5 A LL N S4 8 L6£S 4't94Z- Z'4545- 9'4 Y'4Z6- Z'6LZ- £'ZS15 A 6L N St 6 8925 6'ZStZ- L'9595- L'4 8'646- LIME- 5'6585 A I8 N S4 8 4115 • i • • WORKOVER SUMMARY for C24 -23 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 2006 to allow continued injection under certain criteria. It appears that the current tubing is parted and contains ±8000' of slickline that was lost in the well in 1992. The WL operator speculated the tubing is parted between 4000- 5000'. The last attempt to enter the well was in 2005 but slickline was unable to get below 1200' due to scale. The current tubing will be pulled and/or fished along with the top Baker FHL packer at 8000'. A new injection string will be run with a new packer and a sealbore receptacle that will set on the 3 -1/2" tubing stub at 8078'. The current lowermost casing head section will be replaced with a new conventional casing head that will allow for the installation of a new tubing spool and tubing hanger. Coil tubing will be utilized to clean out the scale and acidize the pay intervals after the new injection tubing has been set. Current Well Status: Injecting 200 BWIPD @ 3500 psi. Well Info: See Attached Procedure & TVD Survey. SSV Report NA as Injector. MASP & Kill Weight: BHP = 4500 psi: (8.4 ppg FIW x 8650' Midperf TVD x 0.052) + 750 SIWHP = 4500 psi. Kill weight: 4500 psi = (0.052) (7971' Top Perf TVD) (x, ppg)5 P ; x = 10.9 ppg + 0.5 ppg = 11.4 ppg mud Mud Recipe will be 8.4 ppg FIW + 180 lb/bbl CaC12 MIT Info: The well has had an Injection Waiver 9.007 since 2006. As seen in the Press & Monitoring file, the well has good integrity on the 7" Longstrong. BOP Ram Configuration: VPR for 2 -7/8" 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. Contact Info: /v1 P5r 3COO J) 5 a • Operations Engineer: Paul Figel, XTO Energy, 432 - 620 -6743, a® 4 -Ac -`� 0 2� /e)(2 Paul figel @xtoenergy.com • Superintendent: Scott Griffith, XTO Energy, 907 - 776 -2506, scott_griffith @xtoenergy.com • • TO ENERGY MASP for C24 -23 (168 -107) Current Well Status: Injecting 200 BWIPD @ 3500 psi. The well has been on injection since 1970. It is unlikely after injecting 8.4 ppg Filtered Inlet Water for over 40 years that the well will experience a kick but for safety purposes, a 10% Oil Cut was used to determine a MASP. 8.4 ppg FIW = 0.437 psi /ft 34 API = 0.3702 psi /ft. Mid Perf TVD: 8630' Top Perf TVD: 7973' 750 psi SI WHP. BHP = (0.437 psi /ft)(8630') + 750 psi = 4521 psi. Phyd = (0.1)(0.3702 psi/ft)(7973') + (0.9)(0.437 psi /ft)(7973') = 3431 psi MASP = 4521— 3431 = 1090 psi Paul Figel Engineering Manager 8 -10 -12 • ENERGY XTO ENERGY INC. MGS C24 -23 EAST FLANK, COOK INLET, ALASKA REPAIR PRESS COMMUNICATION PROCEDURE WELL DATA: SURFACE CASING: 10 -3/4 ", 40.5 #, J55. Set @ 1,830'. Cmt w/ 1,300 sx. PRODUCTION CASING: 7 ", N -80, BTC. Set @ 9,530'. Cmt w/ 960 sx. Surf- 8,070': 26# 8,070 — 9,530': 29# PBTD: 9,441' UPPER COMPLETION: 255 jts 2 -7/8 ", 6.5 #, L80, 8 RD, EUE @ 8,081' (Installed 1991) X Nipple (2.313" ID) @ 355' X Nipple (2.313" ID @ 7948' Baker PBR Seal Bore @ 7981' w/ 33,150# shear 7" Baker FHL Retrievable Packer @ 8000' w/ 50,000# shear XN Nipple (2.205" ID) @ 8038' Baker SBR @ 8081'. Stung over 3' stub of 3 -1/2" tbg from lower completion LOWER COMPLETION: 3 -1/2 ", 9.3 #, N80, 8rd, EUE 8078 -8992' (Installed 1972) Guiberson RH -1 pkr @ 8081' KBG Mandrel #1 @ 8233' Otis `XO' sliding sleeve @ 8268' (closed) Guiberson RH -1 pkr @ 8272' KBG Mandrel #2 @ 8759' (dummy) Otis AO' sliding sleeve @ 8795' (open) Guiberson RH -1 pkr @ 8799' KBG Mandrel #3 @ 8857' (dummy) Otis `XO' sliding sleeve @ 8892' (open) Guiberson RH -1 pkr @ 8896' KBG Mandrel #4 @ 8932' (dummy) Otis AO' sliding sleeve @ 8967' (closed) Guiberson RH -1 pkr @ 8970' Otis `X' Nipple (2.75" ID) @ 8981' Otis `Q' Nipple (2.635 "ID) @ 8992' PERFORATIONS: GN - GO: 8108 -8140 (SS Closed) GR — GS: 8413 -8466' HC — HD: 8702 -8709' HC — HD: 8720 -8758' HD — HE: 8766 -8775' HE — HF: 8824 -8865' HI — HK: 8928 -8942' (SS Closed) HI — HK: 8955 -8967' (SS Closed) HK — HN: 8985- 9110' 7 -6 -12 Y: \PLF\alaska\Procedures \C24 -23 \C24 -23 Repair TCA comm Procedure 7- 6- 12.doc • 2 • HN — HR: 9128 -9185' HN — HR: 9198 -9278' HR — HZ: 9312 -9333' HR — HZ: 9355 -9440' BHST: 170 Deg F BHP: 4500 psi (SI WHP = 750 psi) HOLE DEVIATION: Max 19 Deg f/ 3400 -3700' MD SMALLEST ID: XN Nipple @ 8038' (2.205" ID) CURRENT INJECTION: 200 BWIPD @ 3500 psi as of 7 - - 12. OBJECTIVE: Replace parted tbg w/ fish, Perforate tbg across HI -HK (SS Closed), & Coil tbg acidize HI -HZ. NOTES: • AFE # 1200482 • Slickline fish consists of GLV pulling tool and 8000' of slickline. Slickline parted at surface. It is not known if fish is inside 2 -7/8" tbg or in the annulus as there is speculation that the tbg is parted between 4000 — 5000'. • Expect heavy scale in the tbg as the 1.7" gage ring unable to pass 1234'. • The entire D Compact Wellhead will be replaced which will require cutting & replacing the top 150' of 7" casing. • Need 11" x 13 -5/8" clamp adapter for BOP. Materials Rqd: • 5000 gal Acid System for CT operations to contain these additives: ➢ 10% HCL ➢ gpt Corrosion Inhibitor ➢ ppt Iron Reducing Agent ➢ 2 gpt Surfactant • 200 bbl Gel Pill (2 lbs/bbl FloZan + 3 gal Greencide) (Provided by MI) • 1,000 lbs Soda Ash (MI) • 75,000 lbs CaC12 (400 bbls 11.4 ppg mud) 180 lbs /bbl FIW (Save mud for C24 -26RD & C34 -26) • 60 gal WC1447WR Corrosion Inhibitor (Nalco) • 250 BBL PTS Flowback Tank 7 -6 -12 Y: \PLF\alaska \Procedures \C24 -23 \C24 -23 Repair TCA comm Procedure 7- 6- 12.doc • • 3 PROCEDURE: 1. SI well 2 weeks prior to RU & bleed down. MIRU derrick. 2. Mix 400 bbl 11.4 ppg CaC12 mud. RU mud pumps to tubing. Open the tbg annulus. Circulate to kill well from ±4000- 5000'. Take wellbore fluids to disposal well and recover /maintain the 11.4 ppg Salt mud. 3. SD & monitor well for 60 minutes to make sure well is dead. 4. Notify the AOGCC 48 hrs prior to BOP test. Set BPV. ND WH. Set 11" 5K x 13 -5/8" clamp adapter. NU riser & BOP's. Pull BPV's & set 2 -way check valve. Ensure BOP has VPR pipe rams for 2 -7/8" tbg. Press test BOP's to 250 psi & 5000psi. Send D Compact WH to OS for scrap. w w N 1z hove'sve -rGoc 5 ffl�- V4 (-), 5. MI 8200' 3 -1/2" 15.5# S135 DP & 9 ea 4 -3/4" DC's (Min 2.25" ID). 6. PU on tbg & measure hook weight. POOH & LD 2 -7/8" tbg while checking for NORM. Send tbg to onshore to be sold for scrap. NOTE if SL fish is stuck in tbg. 7. If tbg is parted, RIH w/ Rolling Dog OS or Series 150 (depending on last tbg POOH). Make attempts to recover fish. If unsuccessful, consider 5 -3/4" wash pipe w/ 2 -7/8" tbg cutter. 8. Contingency Plan If WL Fish is Above Tbg Part: a) MU rope spear BHA consisting of Center Prong Rope Spear & Stop Collar w/ Drain Sub, 1 Jt 3 -1/2" Drill Pipe, 4 -3/4" Daily Bumper Jar, 4 -3/4" Daily Oil Jar & 6 ea 4 -3/4" Drill Collars. b) RIH to top of parted tbg. Establish all string weights no less than 200' from top of tbg, or shallower if down weight is seen. Rotate to engage WL. POOH. c) Cont. w/ Step 7. 9. RIH w/ 3.25" spear w/ 4' extension to engage Baker PBR (3.25" ID) @ 7981'. Shear & release pkr w/ 50,000# over -pull minimum. Circ 20 bbl gel sweep. POOH w/ pkr & 81' of tailpipe assembly. 10. RIH w/ dress -off mill to dress off top of the 5' 3 -1/2" tbg stub. BHA to consist of mill, casing scraper for 29# & MAGTRAP. LIGHTLY tag up on tbg stub @ 8078'. Dress -off tbg stub as per instructed. Reverse circ 20 bbl gel sweep. RU SL. (Confirm ID of MAGTRAP for SL tool.) RIH w/ 1.75" tool to check that the ID of 3 -1/2" tbg stub is not collapsed @ 8078'. POOH w/ SL. POOH & LD BHA. 11. RIH w/ HOWCO 7" 26# pkr to test csg. Set pkr @ ± 8000'. 12. Pressure test casing to 2000 psi & observe for 30 min. Report any pressure loss to Midland. If necessary RIH w/ pkr & RBP and isolate leak. 13. POOH w/ pkr. LD DP except for 500'. II 7 -6 -12 Y: \PLF\alaska \Procedures \C24 -23 \C24 -23 Repair TCA comm Procedure 7- 6- 12.doc • • 4 Casing Cut for Csg Spool Removal: 14. MI 4 jts 7" 26# L80 BTC -M. 1 jt to have Guided Skirt welded by pin end (Olgnoonik). 15. RIH w/ HOWCO 7" 26# RBP & set @ 500'. Close pipe rams & press test to 1000 psi. POOH. Drop 500 lbs (20') of sand on top of RBP. 16. MU 7" casing cutter on DP. RIH & cut the 7" csg ±20' below the WH assembly. Circ out any gas. POOH & LD cutter. 17. ND BOP's. 18. Remove the bottom clamp from bottom of D Compact WH. LD WH w/ casing hanger & the 20' 7" casing stub. 19. NU new Cameron clamp x flange casing head. 20. NU BOP. 6D1) 21. Press test the new clamp against the RBP to 3000 psi for 30 min. V 22. RIH w/ 5 -3/4" ITCO Spear w/ 2.0" ID and engage the top of 7" & PU 5000# over string wt. RU Pollard WL. RIH w/ string shot & CCL. Apply recommended torque to 7 ". Fire string shot in collar between 100 -150'. Backoff casing at collar. POOH & LD ±3 jts csg. 23. RU Casing Crew. PU Guided Skirt jt followed w/ 3 reg jts of 7" 26# L80 BTC -M. Slip over collar from previous step & MU threads. Screw on 7" swage w/ 1502 2" connection. RU mud pump and press test the new 7" connection against the RBP to 2000 psi for 30 min. Bleed -off press. RD BOP's. Hang off 7" on slips in WH, make cut and install new Cameron Tubing Spool. 24. Notify the AOGCC 48 hrs prior to BOP test. NU BOP's. Set WH test plug in tbg spool. Press test BOP's to 250 psi & 5000 psi. 25. RIH and wash off sand & retrieve the 7" RBP @ 500'. POOH & LD DP. 26. MI 8350' 2 -7/8" 6.5# L80 + 1% Cr 8rd EUE tbg (inc13% excess). 27. RIH w/ 7" Chrome Retrievable Pkr as follows: 7 -6 -12 Y:\PLF\alaska\Procedures \C24 -23 \C24 -23 Repair TCA comm Procedure 7- 6- 12.doc .. ' • • 5 Item Length, ft Top Bottom 2 -7/8" 6.5# L80 + 1% Cr 8rd EUE 300 0 300 4' Pup Jt, 2 -7/8" 6.5# 1% Cr 8rd EUE 4 300 304 2 -7/8" X Nipple (2.313" ID) 9 Cr 1 304 305 4' Pup Jt, 2 -7/8" 6.5# 1% Cr 8rd EUE 4 305 309 2 -7/8" 6.5# L80 + 1% Cr 8rd EUE 7,616 309 7,925 4' Pup Jt, 2 -7/8" 6.5# 1% Cr 8rd EUE 4 7,925 7,929 2 -7/8" X Nipple (2.313" ID) 9 Cr 1 7,929 7,930 4' Pup Jt, 2 -7/8" 6.5# 1% Cr 8rd EUE 4 7,930 7,934 1 jt 2 -7/8" 6.5# L80 1% Cr 8rd EUE 31 7,934 7,965 7" TIW HM -1 Retrievable Packer (13 Cr) 4 7,965 7,969 3 jts 2 -7/8" 6.5# L80 1% Cr 8rd EUE 93 7,969 8,062 6' Pup Jt, 2 -7/8" 6.5# 1% Cr 8rd EUE 6 8,062 8,068 2 -7/8" XN Nipple (2.205" ID) 9 Cr 1 8,068 8,069 6' Pup Jt, 2 -7/8" 6.5# 1% Cr 8rd EUE 6 8,069 8,075 3 -1/2" x 2 -7/8" TIW SBR (13 Cr) Stabbed in @ 8081' 6 8,075 8,081 * Space out then leave 1 jt out to pump pkr fluid. 28. Prior to setting the packer, circ 260 bbl packer fluid @ 4 BPM containing 60 gal Nalco WC1447WR in 260 bbl FIW. L, C - r O jh" t'' 29. PU landing jt & stab 3 -1/2" SBR onto 3 -1/2" tbg stub at 8078'. 30. Space out & make up and land new SS Tbg Hanger. Run in lock screws to energize hanger seal. 31. RU Slick line & press test lubricator to 4,000 psi. RIH w/ ±1.75" (verify diameter from Step #10) tool to 8200' to verify the SBR is stabbed onto 3 -1/2" tbg sub @ 8081'. 32. RIH w/ PXN plug & set in XN nipple @ 8,068'. Press test tbg to 1,000 psi for 15 min. Monitor falloff. Cont to press up to ±3,500 psi to set pkr. Hold 4,000 psi on the tbg for 15 min. POOH w/ SL. CL1 ar1 - 30ry) , 0 wr i''r55 rin re'etvl red 3 • • .- - - - :: ' : • • • er to theilap, With the 7" Packer set @ 7965' MD, press test the tbg annulus to 2000 psi. (7840' TVD x 0.25 = • s1 psi) and hold for 30 minutes. 34. Set BPV. ND BOP's. NU WH w/ new SS tbg head adapter. Pull BPV. Set 2 -way check. Test WH to 5,000 psi. Pull 2 -way check. 35. RU SL. RIH & pull the PXN plug. RD SL. Rel derrick for Coil Tbg Operation. 7 -6 -12 Y: \PLF\alaska \Procedures \C24 -23 \C24 -23 Repair TCA comm Procedure 7- 6- 12.doc • • 6 Coil Tbg Operation (Work might be done at a later date): / 1. MIRU BJ 1.75" Coil Tbg Unit. RU a filter skid between the mud pits & HP triplex. Install press gauges on the CT, CT Annulus & 2 -7/8" tbg annulus. Make up 1- 11/16" mud motor w/ 2.0" drag bit & circ sub. Contact the AOGCC 48 hrs prior to BOP test. Press test all lines & BOP's to 5,000 psi. MAX Press = 4,000 psi & MAX Fluid Rate for motor = 1.0 BPM. CTU operator to ensure all tools to be calipered before RIH. Smallest ID = 2.205" XN Nipple @ 8068'. 2. Open the CT annulus. RIH w/ CT @ 80 fpm while pumping slick FIW @ 0.5 BPM to 8000'. 3. Slow coil speed to ±10 fpm when approaching 3 -1/2" tbg stub @ 8078'. Once past 8100', cont DH at ± 25 ft/min to PBTD @ 9441'. 4. Drop ball & open circ sub. Pump bottoms up w/ 20 bbls gel pill & 50 FIW @ 1.5 BPM. 5. POOH. LD motor /mill BHA. Move riser aside. 6. RU WL. Install lubricator & press test to 2000 psi. MU 10' tbg punch gun w/ 2 spf. RIH w/ CCL & tbg punch gun. Correlate to Dresser Atlas CCL 10- 13 -83. Fire gun @ 8910 -20' (HI -HK). POOH. RD WL. 7. RU CT riser & press test to 5000 psi. MU jet wash tool on CT. RIH @ 80 fpm to 8000' while circulating I/2 BPM regular FIW. Slow to 10 ft/min from 8000 - 8100'. Cont DH to 9440' @ 25 ft/min. 8. Lay 700 gal (16.6 bbl) 10% HCL @ 1 BPM in the 7" csg from 9440' to 8992' while PUH @ 27 fpm. Cont to lay 300 gal (7 bbl) acid in the 3 -1/2" tbg from 8992 to ±8200' while PUH @ 57 fpm while pumping V2 BPM. Displace w/ FIW. PU CT to 8000' & SD. Let acid soak for 30 min. 9. RIH to 9440' @ 30 fpm & 1.5 BPM while circ out acid with 70 bbl FIW. 10. SI the CT annulus. Sqz 4000 gal acid as follows: • 7" Casing: Pump 2100 gal (50 bbl) 10% HCL while making 3 passes across 9440 - 9000' while pumping @ 0.7 BPM and moving the CT @ 20 ft/min. • 3 -1/2" tbg: Pump 1700 gal (40 bbl) 10% HCL while making 3 passes across 8970 - 8780' while pumping @ 0.7 BPM and moving the CT @ 10 ft /min. 11. Over flush acid with 100 bbl FIW while making 2 passes across the interval from 8780 — 9440' while pumping @ 0.7 BPM and moving the CT @ 10 ft/min. 12. Open CT annulus. POOH @100 fpm. Close swab valve. RD CTU. RWTI. Paul Figel Engineering Manager 7 -6 -12 Y:\PLF\alaska\Procedures \C24 -23 \C24 -23 Repair TCA comm Procedure 7- 6- 12.doc , . • • PLF 4 -5 -12 ENERGY Present Completion MGS C24 -23 WIW 7f, KB: 35' Cook Inlet, Alaska Water Depth: 73' MSL Leg 4, Conductor 32 �, API No.: 50 - 733 - 20145 Tubing: 2 - 7/8 ", 6.5 #, L80 EUE 8rd surf Spud: 11 - 24 - 68 r ; °� 3 9.3 #, N - 80 EUE 8rd 8081 - 8992' Sidetracked from ^11-26 24" Conductor Casing @ 370' Upper Completion Installed 8 -1991 Cameron Type D' Tbg Hanger 4' Pin x Pin pup jt. 10 jts 2 -7/8" 6.5# L -80 8RD EUE Surf Csg: 10 3/4", 40.5 Ib, J55. Otis 'X' Nipple (2.313" ID) @ 355' Set @ 1830'. Cmt'd w/ 1300 sx. 242 jts 2 -7/8" 6.5# L -80 8RD EUE Otis "X" Nipple (2.313" ID) @ 7948' 4 1 jt 2 -7/8" 6.5# L -80 8RD EUE Baker PBR Seal Bore @ 7981'. 33150# shear Poss Parted tbg @ 4000 -5000' (12 -92) 1 1 2 -7/8" to 3- x -over Baker `FHL' Hyd. ret. Pkr @ 8000'. 50000# shear 1 jt 2 -7/8" 6.5# L -80 8RD EUE Otis `XN' (2.205" ID) nipple @ 8038' 1 jt 2 -7/8" 6.5# L -80 8RD EUE Baker 'SBR' at 8081'. Stung on 3' stub of 3-'/2" tbg. Lower Completion Installed 8 - 72 3-Y2" Tbg stub top @ 8078' /! 'eY, Otis 'X' Nipple (2.75" ID) 8981' FISH: GLV Pulling Tool + 8000' SL.' Otis 'Q' Nipple (2.635" ID) @ 8992' Poss Fish could be on Tbg ann. 4 .';'/ ' (12 -8 -92) / 7/ ,, ito ,..--„,„ -..--4 Guiberson RH -1 pkr @ 8081' ' PM— q KBG Mandrel ndrel #1 @ 8233' � ,� �'' GN - GO: 8108' - 8140' Otis `X SS 8268' @ 8268 (closed) �: Collapsed Csg 8120 -30'. Repaired w/ csg roller in Guiberson RH -1 pkr @ 8272' "4144 1972 before running isolation packers. GR -GS: 8413' -8466' HC -HD: 8702' -8709' KBG Mandrel #2 @ 8759' (dummy HC - HD: 8720' - 8758' Otis 'XO' SS @ 8795' (Open) OL, INNINIu _ HD 8766' - 8775' Guiberson RH -1 pkr @ 8799' ��■''� ' KBG Mandrel #3 @ 8857' (dummy) HE - HF: 8824' Otis `XO' SS @ 8892' (Open) g. Guiberson RH -1 pkr @ 8896' -- HI - HK: 8928' - 8942' KBG Mandrel #4 @ 8932' (dummy) , ^_ — Otis X0' SS @ 8967' (closed)%" HI - HK: 8955' - 8967' Guiberson RH -1 pkr @ 8970' // ;" Longstring: 7" N80 BTC Set @ 9530 HK -HN: 8985' -9110' 26 #: 37 -8070' & 29 #: 8070 - 9530'. HN -HR: 9128' -9185' Cmt w/ 960 sx. HN -HR: 9198' -9278' r if P PBTD: 9441'' HR -HZ: 9312' -9333' TD: 9555' i ' HR -HZ: 9355' -9440' . • 0 PLF 7 -3 -12 E ( 1 u O NERGY Proposed Completion MGS C24 -23 WIW KB: 35' . F Cook Inlet, Alaska Water Depth: 73' MSL Leg 4, Conductor 32 dr A PI No.: 50- 733 -20145 Upper Completion Installed: Spud: 11 -24 -68 TO 0 fo 4' Pup Jt, 2 -7/8" 6.5# 1% Cr 8rd @ 300' Sidetracked from C11 -26 44 2 -7/8" X Nipple (2.313" ID) 9Cr @ 304' 4' Pup Jt, 2 -7/8" 6.5# 1% Cr 8rd @ 305' 24" Conductor Casing @ 370' ±246 jts 2 -7/8" 6.5# L80+1% Cr 8RD EUE 4' Pup Jt, 2 -7/8" 6.5# 1% Cr 8rd @ 7925' 2 -7/8" X Nipple (2.313" ID) 9 Cr @ 7929' 4' Pup Jt, 2 -7/8" 6.5# 1% Cr 8rd @ 7930' Surf Csg: 10 3/4 ", 40.5 Ib, J55. 1 jt 2 -7/8" 6.5# L80+1% Cr 8RD EUE @ 7934' g 7" TIW HM -1 Ret Pkr (13 Cr) @ 7965' Set @ 1830'. Cmt'd w/ 1300 sx. 3 jts 2 -7/8" 6.5# L80+1% Cr 8RD EUE 6' Pup Jt, 2 -7/8" 6.5# 1% Cr 8rd @ 8062' 2 -7/8" XN Nipple (2.205" ID) 9Cr @ 8068' 6' Pup Jt, 2 -7/8" 6.5# 1°/0 Cr 8rd @ 8069' 3.5" x 2 -7/8" TIW SBR @ 8081' Lower Completion Installed 8-4 -72 3- Tbg stub top @ 8078' Otis 'X' Nipple (2.75" ID) @ 8981' Otis 'Q' Nipple (2.635" ID) @ 8992' pr . reo I g r :10 °.40 0 10-71,..PAI 1.- , k Ai 10 Guiberson RH -1 pkr @ 8081' GN - GO: 8108' - 8140' KBG Mandrel #1 @ 8233' ' � - Otis 'XO' SS @ 8268' (closed) Collapsed Csg 8120 -30 Repaired w/ csg roller in Guiberson RH -1 pkr @ 8272' r� C.A 1972 before running isolation packers. /4 GR -GS: 8413' -8466' HC -HD: 8702' -8709' KBG Mandrel #2 @ 8759' (dummy) _- HC - HD: 8720' - 8758' Otis `XO' SS @ 8795' (Open) 0 - - -= HD - HE: 8766' - 8775' Guiberson RH -1 pkr @ 8799' / ►�� KBG Mandrel #3 @ 8857' (dummy) ■ HE - HF: 8824' - 8865' Otis `XO' SS @ 8892' (Open) ■� -__� �/ =� Tbg Punch @ 8910 -20' Guiberson RH -1 pkr @ 8896' _ KBG Mandrel #4 @ 8932' (dummy) HI - HK: 8928' - 8942' Otis'XO' SS @ 8967' (closed ir_____ HI - HK: 8955' - 8967' Guiberson RH - 1 pkr @ 8970' - / Longstring: 7" N80 BTC Set @ 9530'. HK -HN: 8985' -9110' 26 #: 37 -8070' & 29 #: 8070 - 9530'. HN -HR: 9128' -9185' Cmt w/ 960 sx. HN-HR: 9312' HR: 9198' _9333' 9278' PBTD: 9441' TD: 9555' r jl�� %�%l HR-HZ: HR -HZ: 9355'-9440' • • ee k CAMERON XTO PLATFORM C Well 24 -23 Equipment Current Wellhead 7 -2 -12 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 m - rn o �■ m O_O o ©o 00 / R -27 1 N • i '' -I �I 1 ! - Pneumatic .' � 6 O t -, 0. 00 Tubing Head Adapter Type D API 5K ( #10 Clamp) Hub Bottom x 2 -9/16 API 5000 Top L__] R -53 Ring Gasket Bottom R -27 Ring gasket Top �! 8" 9' 1" om O u _° it Ectli 31 7 i ll 111 ummo Lowermost Casing Head Type D Compact : o % 11" 3K (#9 Clamp) Hub x 11 API 5K ( #10 Clamp) Hub Top _ R-53 MODIFIED Ring Gasket Bottom . I 2 -1/16 API 5K R -53 Ring Gasket Top VII 7 R -24 Ring Gasket 4' 2" Annulus Outlets are 2 -1/16 API 5K R -24 Ring Gasket I did/ I 2' 11" ¶ 2 -1/16 API 3K 2' 1" ,-53 MODIFIED R -24 Ring Gasket .‘ . • • .. e i t CAMERON XTO PLATFORM C Well 24 -23 INJECTOR REPLACEMENT EQUIPMENT 2012 Well currently has a Cameron Type D Compact Wellhead Existing 7" Casing will be cut to allow removal of the D Compact Housing. A new Casing Housing will be installed, the 7" tied back and a new Tubing Spool installed. We will also replace the Tubing Hanger, Adapter and Tree *Equipment to be confiqured as shown war Trees confiqured the same as existing ,, �,, equipment currently on Wells per photographs , ■.- O® o— o�COI)� J Replacement 2 -9/16 5000 Tree © 3 o 2 -1/16 5000 Wing HWO o. With 2 -1/16 5K Wing ° )o ° = Pressure Side to Injection ill O OI -- 1M1 800 \ 0 J Replacement Tubing Head Adapter "— 7 -1/16 x 2 -9/16 Stainless Adapter 1111 11111M alp Replacement Tubing Hanger PN UNKNOWN ' 7 x 2 -7/8 EUE 8rd Stainless PN UNKNOWN I i :I: Replacement Tubing Spoo! 1 !I T CAMERON N 11 "5K x 7 -1/16 5K Top III I�UM- 0. 01 _ Replacement Secondary Seal PN Unknown 1 - PN UNKNOWN it NX Bottom Prep nu_ 111111 . �''��_ = �.��'"= Replacement Slips Replacement Casing Head imi . '� PN UNKNOWN PN UNKNOWN z- -----, ill III I �O`6 O l � 11 Flow Flow line Nipple unr Hydril r 13 5/8" Sm 13 5/8" 5m Annular double ram preventer i rrn m rn rrn m I 1 13 518" 5m Cameron k' Pipe rams • • • I= a 'I U • ■ ( 1 <) PI L ® , 13 Blind 5m Cameron l �� Blind Rams a�� • u I I I I - $ f 'I 0 _i C � c ��II 'I 01 IN C O ' i • HCR • • ---II. 2 1116" Kill Line I m m m m' 3 1!8 "Choke Line 21/16" 3 1/8" 3 1/8" 5m Sm Sm Hydraulic Manual Manual Valve Valves valve 13 5/8 Sm riser 13 5J8" 5m l ;uu w l.0 LIE w 1 Mud Cross with 3 1/8" outlets • • ,9 Regg, James B (DOA) Pr6 1 (41070 From: Paul_Figel @xtoenergy.com Sent: Monday, August 06, 2012 6:25 AM y tilt( v To: Regg, James B (DOA); Scott_Griffith @xtoenergy.com; Barney_Phillips @ xtoenergy.com; Greg_Duggin @xtoenergy.com; Schwartz, Guy L (DOA) Subject: XTO Energy - C24 -23 (1681070) Rate and Pressure Monitoring July 2012 AIO # 9 -007 Attachments: C24 -23 Rate and Pressure Monitoring July 2012 (AIO # 9- 007).xlsx Attached is the July 2012 injection rate and wellhead pressure monitoring reports for the Middle Ground Shoal C24 -23 as required by Administrative A proval AIO No. 9.007. 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 SAY 0 7 2013 Office: 432 - 620 -6743 Cell: 432 - 553 -5217 Fax: 432 - 687 -0862 1 • • XTO Energy - C24 -23 (1681070) Rate and Pressure Monitoring Administrative Approval AIO No. 9.007 5,000 — dr CsgxTbg Annulus Pressure 500 ..- r.�Injection Pressure 4,500 tlnjection Rate (bbl /d) 450 ■Surface Casing Pressure d 4,000 400 a; N CL N • 3 —� 350 0 C U O d 3,000 300 o f a) — a1 °5 2,500 250 a N N 7 d 200 3 c 2,000 • •T• co Q c N i� � H U 1 150 x m 0) 0 o 1,000 100 co 500 50 0 . 1 . 1 . 1 • 1 . 1 • 1 • 1 1 1 . 1 . 1 • 1 • 1 • 1 • 1 0 o ,Nry o .0" o ,kry , e ' e o ^ry o ,..'1" o ^ry o� O�� o ^ � o ^ry ,,, ,,,N ‘1 ' 1 A AV AV AV A A A Av Av A • • C24 -23 (1681070) Rate and Pressure Monitoring Administrative Approval AIO No. 9.007 Surf Injected Casing Annulus Injection Comments [bbl] [psig] [psig] [psig] Hrs Down 7/1/2012 200 25 3,450 3,450 0 7/2/2012 199 25 3,450 3,400 0 7/3/2012 196 25 3,450 3,400 0 7/4/2012 198 25 3,450 3,400 0 7/5/2012 202 25 3,450 3,500 0 7/6/2012 205 25 3,450 3,500 0 7/7/2012 154 25 3,450 3,500 8 7/8/2012 24 25 3,450 3,500 22 w/f down 7/9/2012 301 25 3,450 3,500 0 7/10/2012 182 25 3,450 3,500 4 w/f down 7/11/2012 218 25 3,450 3,500 0 7/12/2012 210 25 3,450 3,500 0 7/13/2012 212 25 3,450 3,500 0 7/14/2012 218 25 3,450 3,500 0 7/15/2012 213 25 3,450 3,500 0 7/16/2012 213 25 3,450 3,500 0 7/17/2012 225 25 3,450 3,500 0 7/18/2012 250 25 3,450 3,500 0 7/19/2012 247 25 3,450 3,500 0 7/20/2012 233 25 3,450 3,500 0 7/21/2012 246 25 3,450 3,500 0 7/22/2012 242 25 3,450 3,500 0 7/23/2012 245 25 3,450 3,500 0 7/24/2012 261 25 3,450 3,500 0 7/25/2012 265 25 3,450 3,500 0 7/26/2012 262 25 3,450 3,500 0 7/27/2012 266 25 3,450 3,500 0 7/28/2012 281 25 3,450 3,500 0 7/29/2012 292 25 3,450 3,500 0 7/30/2012 273 25 3,450 3,500 0 7/31/2012 284 25 3,450 3,500 0 CsgxTbg Annulus & Injection Pressure s N N co co . • A U1 U1 O U1 O U1 O (.71 0 (J1 O O O O O O O O O O O O O O O O O O O O O O 11112011 ' 2/1/2011 ;, •1 I 3/1/2011 (1) _ ' a 0 o o x 4/1/2011 - --II I 0 7 7 Cr v -0 up D 51112011 111111110 v ° m N = 6/112011 CD • ��w� , D co 7/1/2011 1 _ ��N (') 8/1/2011 = 7). t:) • W 9/1/2011 111— .. I f CD 10/1/2011 'D CO r OW O 11/1/2011 [_emu• ■41 -0 O 12/1/2011 0 1.66h1 3 x iim _ PIUS , 2) r.l. 1/1/2012 M. ,,,04iii : D 2) CL 2/112012 mi.... — ...." Z 3/112012 i El Ili 4/1/2012 O = O V 5/1/2012 d11111111111 O 6/1/2012 1 °C' e=: 7/1/2012 -s (Q 8/1/2012 I 0 U1 — ,� N N W co A A (.71 O O 01 O (J7 O U1 0 (1 O O O O O O O O O O Surface Casing Pressure & Injection Rate • S ('& 'o Regg, James B (DOA) From: Paul_Figel @xtoenergy.com Sent: Thursday, July 12, 2012 7:22 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 - C24 -23 (1681070) Rate and Pressure Monitoring June 2012 AIO # 9 -007 Attachments: C24 -23 Rate and Pressure Monitoring June 2012 (AIO # 9- 007).xlsx Attached is the June 2012 in rate and - .- -• •ressure m•nitorin• re•• is for the Middle Ground Shoal C24 -23 as required by Administrative Approval AIO No. 9.007. The rate and pressure continue to indicate that there has been no change in the well's mechanical condition. Paul Figel Engineering Manager SCANNED MAY 0 7 2013 XTO Energy Inc. Midland, TX Office: 432 -620 -6743 Cell: 432 - 553 -5217 Fax: 432 - 687 -0862 1 • • XTO Energy - C24 -23 (1681070) Rate and Pressure Monitoring Administrative Approval AIO No. 9.007 5,000 ■CsgxTbg Annulus Pressure 500 ...t*�Injection Pressure 4,500 ■lnjection Rate (bbl /d) 450 ■Surface Casing Pressure m 4,000 _ 400 a; N re R d 3,500 — — — 350 0 O d 3,000 300 5 c d 0 5 2,500 250 N N N 7 y c 2 ,000 200 1 CD Q c p, N I- 1,500 150 �j x 0 0) 0 a 0 1.000 100 to 500 50 0 • 1 1 1 . 1 • 1 I 1 1 • 1 1 1.1/ 1 1 • 1 • 0 \L p \y 0 \y 0 \y0 X 10 \y 0 \ ti0 \ y 0 X 1 0 \ ,y0 \ , y 0 \ , 1 0 �, �, \ 1 O 4 4 4 4 4 \ �. \ �, .' • ' 1' \ti 1 6 1' 6 1 6 �0 6 6 • ro 0 6 0 . S • C24 -23 (1681070) Rate and Pressure Monitoring Administrative Approval AIO No. 9.007 Surf Injected Casing Annulus Injection Comments [bbl] [psig] [psig] [psig] Hrs Down 6/1/2012 396 22 3,450 3,500 0 6/2/2012 386 22 3,450 3,500 0 6/3/2012 396 22 3,450 3,500 0 6/4/2012 401 22 3,475 3,500 0 6/5/2012 407 22 3,475 3,500 0 6/6/2012 369 22 3,460 3,500 0 6/7/2012 358 25 3,500 3,550 0 6/8/2012 349 25 3,500 3,550 0 6/9/2012 409 25 3,500 3,550 0 6/10/2012 380 25 3,500 3,550 0 6/11/2012 288 25 3,500 3,550 0 6/12/2012 314 25 3,500 3,550 0 6/13/2012 282 25 3,500 3,550 0 6/14/2012 294 25 3,500 3,550 0 6/15/2012 245 25 3,500 3,550 0 6/16/2012 224 25 3,500 3,550 0 6/17/2012 227 25 3,500 3,550 0 6/18/2012 217 25 3,500 3,550 0 6/19/2012 215 25 3,500 3,550 0 6/20/2012 155 25 3,500 3,550 7 turbine down 6/21/2012 0 20 825 825 24 turbine down 6/22/2012 0 20 825 825 24 turbine down 6/23/2012 73 20 3,450 3,500 20 turbine down 6/24/2012 201 23 3,450 3,500 0 6/25/2012 196 25 3,450 3,500 0 6/26/2012 194 25 3,450 3,500 0 6/27/2012 194 25 3,450 3,500 0 6/28/2012 195 25 3,450 3,450 0 6/29/2012 197 25 3,450 3,450 0 6/30/2012 197 25 3,450 3,450 0 CsgxTbg Annulus & Injection Pressure N N co W A A 01 O O O O O O O O O O O O O O O O O O O O O 1/1/2011 - 2/1/2011 3/1/2011 = n _ Ill i F 0 0 X X n CD 7 7 C O O - 4/1/2011 --.11 v D 0 up 5/1/2011 "0 0 CD (n = 11111110 m a -o CD 6/1/2011 IMAM c cn * �� Q 7/1/2011 2 N p �_, 11111111 = � 8/1 /2011 W .72111111111111 MO ,-1- 9/1/2011 LT _7&A4INI 1-1- 10/1 /2011 111111111111 Ihr- D " -0 o 11/1/2011 [ —.ammalWIIIIIIII O 12/1/2011 �� - m OEM - � m 1 /1 /2012 _ _ � � O Q le IIIIMIMM.IL.L _ - Z 2/1/2012 • CD 3/1/2012 � �� _ � • N 4/1/2012 1111&...,■. 5/1/2012 prow dill. = O 6/1/2012 1111111111111111ff IIPC. -- 7/1/2012 111 III O U1 _, _, N N co W . ? U1 O o U1 O U1 O (T O C.11 O O o O O O O O O O Surface Casing Pressure & Injection Rate • • • • AG s c 2A-2-3 Prig 4,6/07(:) Regg, James B (DOA) ct From: Paul_Figel @xtoenergy.com Sent: Wednesday, June 06, 2012 6:49 AM % t 47 /hz_ To: Regg, James B (DOA); Scott_Griffith @xtoenergy.com; Barney_Phillips @ xtoenergy.cbm; Greg_Duggin @xtoenergy.com; Schwartz, Guy L (DOA) Subject: XTO Energy - C24 -23 (1681070) Rate and Pressure Monitoring May 2012 AIO # 9 -007 Attachments: C24 -23 Rate and Pressure Monitoring May 2012 (AIO # 9- 007).xlsx Attached is the May 2012 injection rate and wellhead pressure monitoring reports for the Middle Ground Shoal C24 -23 as required by Administrative Approval AIO No. 9.007. 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 JUL 3 2012 Fax: 432 - 687 -0862 1 • • XTO Energy - C24 -23 (1681070) Rate and Pressure Monitoring Administrative Approval AIO No. 9.007 5,000 — CsgxTbg Annulus Pressure - 500 ••••+ ■Injection Pressure 4,500 - •■•■• Injection Rate (bbl /d) 450 Surface Casing Pressure E 4,000 400 0 c is 0 r 0 a 3,500 " l li Y k li k I ii 1 11 Y Y Y Y Y 41i li Ai Ai Y Y ii i 350 0 c 0 o 0 3,000 300 .E O °5 c y ° 2,500 250 0 N to 3 y d c 2,000 200 Q c N H • 1,500 150 (j x 0 ✓ 1,000 100 2 U) 500 50 0 + I- - 1 . 1 . 1 • 1 . 1 . 1 1 _ - 4 . 1 . 1 1 . 1 . 1 - 0 \ , y 0 \ ,10 \ , 1 0 \ry \ ,y0 \ ,y0 \ ,y0 \ ,y0 \ ,y0 \ ,10 \ ry0 \ , ti 0 \ , y 0 \ ,, 0 \ , y 0 x , 1 0 <.'N 0�9 0 �g 0 �1 0 �o i 4 ' . 4 4' 4' 4 4 %^ 4 ' k 4 ' <41 '� 01 0 4' • • C24 -23 (1681070) Rate and Pressure Monitoring Administrative Approval AIO No. 9.007 Surf Injected Casing Annulus Injection Comments [bbl] [psig] [psig] [psig] Hrs Down 5/1/2012 198 20 3,450 3,500 0 5/2/2012 161 20 3,450 3,500 0 5/3/2012 157 20 3,450 3,500 0 5/4/2012 155 20 3,450 3,500 0 5/5/2012 197 20 3,450 3,500 0 5/6/2012 189 20 3,430 3,450 0 5/7/2012 218 20 3,450 3,500 0 5/8/2012 232 20 3,450 3,500 0 5/9/2012 234 20 3,450 3,500 0 5/10/2012 206 20 3,450 3,500 0 5/11/2012 117 20 3,450 3,500 8 Pump down 5/12/2012 107 20 3,450 3,500 8 Pump down 5/13/2012 115 20 3,450 3,500 0 5/14/2012 151 20 3,450 3,500 0 5/15/2012 157 20 3,450 3,500 0 5/16/2012 165 20 3,450 3,500 0 5/17/2012 243 20 3,450 3,500 0 5/18/2012 350 20 3,450 3,500 0 5/19/2012 246 20 3,450 3,500 0 5/20/2012 314 20 3,450 3,500 0 5/21/2012 352 21 3,475 3,500 0 5/22/2012 363 21 3,475 3,500 0 5/23/2012 321 21 3,475 3,500 0 5/24/2012 318 20 3,475 3,500 0 5/25/2012 355 20 3,475 3,500 0 5/26/2012 382 20 3,475 3,500 0 5/27/2012 393 20 3,475 3,500 0 5/28/2012 385 23 3,475 3,500 0 5/29/2012 394 23 3,475 3,500 0 5/30/2012 384 23 3,475 3,500 0 5/31/2012 379 22 3,450 3,500 0 CsgxTbg Annulus & Injection Pressure o c o (71 o (71 0 o 0 0 0 0 0 0 o 0 0 0 0 0 0 1/1/2011 ' I 2/1/2011 0 1 1111 3/1/2011 0 C C X i n ° ° -I CD m z ,Sr 4/1/2011 - 11 v m 0 ci) Mahar -- Q = � N N 5/1/2011 I �s a m CD C N N 6/1/2011 WM= 11 a :::::: cn N t 2) 9/1/2011 - � • 00 D _ 10/1/2011 "0 .-1 73 O O X 11/1/2011 InlaillAl < E el 12/1/2011 �. /111 > CD 1/1/2012 NW Z - 0 O • CD _ _ = tD 2/1/2012 1111 O lit O N O 3/1/2012 - ,r�• - ~ CD 4/1/2012 � S 5/1/2012 �� 6/1/2012 ' o Vl N N co W A A O O U1 O al O (71 O cn O O O O O O O O Surface Casing Pressure & Injection Rate • • Regg, James B (DOA) From: Paul_Figel @xtoenergy.com '2P 7 6 111z- Sent: Thursday, May 03, 2012 5:12 AM 1 To: Regg, James B (DOA); Scott_Griffith @xtoenergy. om; Barney_Phillips @xtoenergy.com; Greg_Duggin @xtoenergy.com; Schwartz, Guy L (DOA) 4 , 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. Midland, TX Office: 432 - 620 -6743 Cell: 432 - 553 -5217 Fax: 432 - 687 -0862 SCSIAMEA) JUN 4 ZU ?Z 1 5l3(Iz..- XTO Energy - C41 -23LN (2042360) Rate and Pressure Monitoring Administrative Approval A1O No. 9.009 5000 - -- r TBG Annulus [psig] 1000 W Injection [psig] - — +-- Injection Rate (bbl /d) 4500 900 - Surface Casing Pressure 3 4000 - -A— 7" Intermed [psig] m 800 U) co - 2 • L R a 3500 .. - 700 ft a O �. �. — Z od 3000 - 600 N _ i I a 2500 500 2 as °5 — N a) 3 2000 400 = d c - c _ 1500 .0 300 m Ii— as 1000 200 co • 500 - 100 o'`ti ,,?,,,, • • 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 XTO Energy - C41 -23LN (2042360) Approval Rate AIO and No. Pressure Monitoring Administrative 9.009 5000 TBG Annulus [psig] 1000 WH Injection [psig] 4500 --�-- Injection Rate (bbl /d) 900 Surface Casing Pressure 4000 —e-- 7" Intermed [psi 800 2 • oil �v ft 3500 �' a 700 ? , ,_. im i 3000 600 L mom" 'c a d X 2500 , 500 v otS °' E In 2000 ; ° 1 d 400 w c c Q 1500 300 v co t 1000 200 cn • 500 ` - ii '" .r -. :00 im .,,, 1,01■1' 0 mit , y 0 ry 0 , ry 0 ry 0 , ry o ,�o �O e f ry o ry 0 , �O , '' ry 0 �O , �O , ry 0 ry 0 , , ry 0 �O , �O V O , , ,� ry 0 ti 0 �O �O ^�►�� QN t r o d Cl ° � � o��o� � � "VA\ei, c eb�Ncb A \ 1� \ \ ry' Nt R , ��L N �� \^ 1��► ��^ D�tio� ^��ry ^O �g��o�� l � 070 A 1 Regg, James B (DOA) From: Paul_Figel @xtoenergy.com 1 4//7411. Sent: Monday, April 09, 2012 6:09 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 - C24 -23 (1681070) Rate and Pressure Monitoring Feb & March 2012 AIO # 9 -007 Attachments: C24 -23 Rate and Pressure Monitoring Feb & March 2012 (AIO # 9- 007).xls Attached is the Feb & March 2012 injection rate and wellhead pressure monitoring reports for the Middle Ground Shoal J P 9 p C24 -23 as required by Administrative Approval AIO No. 9.007. 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 APR 1 7 2012 Fax: 432 - 687 -0862 1 XTO Energy - C24 -23 (1681070) Rate and Pressure Monitoring Administrative Approval AIO No. 9.007 5000 500 CsgxTbg Annulus Pressure Injection Pressure 4500 — +—Injection Rate (bbl /d) 450 Surface Casing Pressure d 4000 400 d • to Cr. - 3 50 � A = 3500 - . . - - -- - - - - -.� - - -- --- - - - -.. -- O V 0 O w 3000 300 - C L cn 2500 250 N 7 N d C CL Q 2000 200 CD cn 150 U cs, 1500 d v U 't '1116111 = 1000 100 500 50 o 0 o0 ,A0 ‘P o'` ti o ^ ti o'` I' o 0 o 0 o 0 o 0 o ' ` % o 0 o 0 o ' ` "1' o 0 �\\ \1• rt. (L ti �\� ti p'` ^\ � ti �ti ^\ � � y � ti� '\ � � '��\� ^ �� o\ � ��`` 4' 4 � 3 �ti �\ry � � `� o\� CsgxTbg Annulus & Injection Pressure N N W W A to O O O O O O O O O O O O O O 1/1/2011 1/15/2011 1/29/2011 _ 2/12/2011 - 7 7 2/26/2011 - f m‘ ( ( c x 3/12/2011 - 1 1 - CD 7 5 C Cr 2 x D 3/26/2011 a I = ) CO 7 m 4/9/2011 - v 0- FP cn = 4/23/2011 ;. 0 a c u m 5/7/2011 _ .. m D 5/21/2011 Q 6/4/2011 - WM - 2 0 Iv 6118/2011 gIr 'p 7/2/2011 W 7/16/2011 I ._ 713012011 _ P. 0) 8/13/2011 , ..� O 812712011 __ _ - '.1 9/10/2011 -0 O 9/24/2011 < x 10/8/2011 'au Mil lillihr - 2) r+ 10/22/2011 —. >< _ __ D DJ 11/5/2011 ,. _ 1 Q z 0. 11/19/2011 „11•111 ' Z 12/3/2011 .7r10111 0 CD 12/17/2011 co N W.' p N 12/31 /2011 - - C O 1/14/2012 _ _ -.I CD 1/28/2012 di..a... - -- - E O 2/11/2012 = 2/25/2012 _ - "} O 3/10/2012 — 3/24/2012 (Q 4/7/2012 4/21/2012 O cn - - N N W CO A 4, O 0 Ui O ui O Ui O Cli O O O O O O O O Surface Casing Pressure & Injection Rate • • • • Regg, James B (DOA) From: Paul_Figel @xtoenergy.com ;� a Sent: Monday, February 20, 2012 10:18 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 - C24 -23 (1681070) Rate and Pressure Monitoring JAN 2012 AIO # 9 -007 Attachments: C24 -23 Rate and Pressure Monitoring JAN 2012 (AIO # 9- 007).xls 4 1 Attached is the Jan 2012 injection rate and wellhead pressure monitoring reports for the Middle Ground Shoal C24 -23 as required by Administrative Approval AIO No. 9.007. 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 E .�' zap` 1 XTO Energy - C24 -23 (1681070) Rate and Pressure Monitoring Administrative Approval AIO No. 9.007 5000 - - Series3 500 a Series4 4500 S Series1 450 s Series2 4000 400 w • N C . • 3500 e 350 O lirp7 C d 3000 - 300 C � ots O 2500 250 O 7 0. C 2000 -, _ 200 0) 0) ti) CS 0 1500 - - 150 v Cl) as V 0 • 1000 - - 100 ° 500 - 50 0 i 0 1/1/2012 1 /5/2012 1/9/2012 1/13/2012 1/17/2012 1/21/2012 1/25/2012 1/29/2012 • 0 C24 -23 (1681070) Rate and Pressure Monitoring Administrative Approval AIO No. 9.007 Surf Injected Casing Annulus Injection Comments [bbl] [psig] [psig] [psig] Hrs Down 1/1/2012 269 0 3425 3400 0 1/2/2012 275 0 3425 3400 0 1/3/2012 257 0 3425 3400 0 1/4/2012 161 0 3425 3400 0 1/5/2012 160 0 3425 3450 0 1/6/2012 151 0 3425 3450 0 1/7/2012 157 0 3425 3450 0 1/8/2012 174 0 3425 3450 0 1/9/2012 223 0 3450 3500 0 1/10/2012 241 0 3450 3500 0 1/11/2012 357 0 3450 3500 0 1/12/2012 222 0 3450 3500 0 1/13/2012 191 0 3450 3500 0 1/14/2012 346 0 3450 3500 0 1/15/2012 334 0 3450 3500 0 1/16/2012 328 0 3450 3500 0 1/17/2012 313 0 3450 3500 0 1/18/2012 347 0 3450 3500 0 1/19/2012 352 0 3450 3500 0 1/20/2012 329 0 3450 3500 0 1/21/2012 346 0 3450 3500 0 1/22/2012 339 0 3450 3500 0 1/23/2012 351 0 3450 3500 0 1/24/2012 343 0 3450 3500 0 1/25/2012 287 0 3450 3500 0 1/26/2012 226 0 3425 3500 0 1/27/2012 223 0 3425 3500 0 1/28/2012 299 0 3425 3500 0 1/29/2012 331 0 3425 3500 0 1/30/2012 341 0 3425 3500 0 1/31/2012 312 0 3425 3500 0 CsgxTbg Annulus & Injection Pressure o (! 0 CA 0 � 0 0 o 0 0 0 0 0 1/1/2011 I 1/15/2011 1/29/2011 ii. 2/12/2011 2/26/2011 t - m s s Q 0 co 3/12/2011 r II v v T v 1 cD cn 3 m 2 C 3/26/2011 F a CD 4/9/2011 - m u, , CO m 4/23/2011 CL • I 5/7/2011 3 N 5/21/2011 - - -- - . N 6/4/2011 _ — 6/18/2011 gi SO. H — 7/2/2011 �� • CD > 0 7/16/2011 73 O 7/30/2011 O 73 8/13/2011 < — — CD 8/27/2011 _ — 9/10/2011 - 0 0 0. 9/24/2011 - 10/8/2011 CD 10/22/2011 -- AL 0 • 11/5/2011 ?MIL - ? 1 ® CD 11 /19/2011 4 ... C ", 0 12/3/2011 3 0 12/17/2011 12/31 /2011 -- 3e 1/14/2012 i.. __ — _ 1/28/2012 I, `..- - __ 0 CA ns N c..3 e...1 0 0 0 (7! o c?i o c7 0 0 0 0 0 0 0 0 Surface Casing Pressure & Injection Rate • • • 0 Tr U, � 1 / SEANPARNELLGOVERNOR ALASKA OIL AND GAS 333 W. 7Ih AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE ALASKA 99501 - PHONE (907) 279 -1433 / FAX (907) 276 -7542 AMENDED ADMINISTRATIVE APPROVAL AREA INJECTION ORDER 9.007 Mr. Paul Figel Engineering Manager XTO Energy 4011 MAR (.l 1 ( a1 200 North Loraine, Suite 800 Midland, TX 79701 RE: MGS C24 -23 (PTD 1681070) Administrative Approval Revision Middle Ground Shoal (MGS) W, F. G Oil Pool Dear Mr. Figel: In accordance with Rule 6 of Area Injection Order (AIO) 09.000; on June 26, 2006 the Alaska Oil and Gas Conservation Commission (AOGCC or Commission) approved continued operation of MGS C24 -23 with tubing by inner annulus (TxIA) communication. AIO 9.007 restated observation and reporting obligations originally imposed in the Commission's letter of September 30, 1993. XTO has complied with the requirements and the operating information continues to demonstrate that the well structure remains competent and the injected fluids are being placed into the intended production intervals. All aquifers in the Middle Ground Shoal Field have been exempted [40 CFR 147.102 (b) (2) (iii)]. The Commission further amends this approval to clarify that testing of the well shut -in equipment linked to the well's outer annulus pressure includes both the shut -down valve and the mechanical or electrical pressure detection device. A recent review of the well operating conditions revealed that the surface injection pressure is 3500 psi which is 48% of the published minimum internal yield pressure (7240 psi) of the 7 ", 26 # /ft, N -80 production casing. The production casing is competent, however if a leak were to develop, the 10 -3/4 ", 40.5 # /ft, J -55 surface casing could fail when subjected to the surface injection pressure which calculates to 111% of published minimum internal yield pressure (3130 psi). To protect against overpressure and potential failure of the surface casing. the Commission now requires that XTO install engineering controls on the outer annulus (OA) of MGS C24 -23. With such controls 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 revised administrative approval to continue water injection only in MGS C24 -23 is conditioned upon the following: 1. Injection is limited to WATER ONLY. • • A10 9.007 (Amended) November 1, 2010 Page 2 of 2 2. XTO shall monitor and record tubing.. inner annulus and outer annulus (T /I /O) pressures and injection rate daily; 3. XTO shall submit to the AOGCC a monthly report of well pressures, injection rates, and pressure bleeds for all annuli; 4. A pressure test of the combined tubing and inner annulus (CMIT) is NOT required as stated in the Commission's letter dated September 20, 1993; 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 « for future - i'' e . 0 DONE An .••rage, Alaska and dated Ter 1, 2010.a J . • Daniel T eamount, Jr. Cathy ' , Foerster Jor.r an ` ` Chair, ommissioner Com issioner Comm - net r �3f�t h ti� 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 tiled. 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 Conrrnission mails, OR 30 days if the Commission others se 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 he filed within 33 days after the date on which the Commission mails, OR 30 days if the Commission otherwise distributes, the order or decision on reconsideration. As provided in AS 31..05,080(b), "[Elbe questions reviewed on appeal are limited to the questions presented to the Commission by the application for reconsideration." In computing a period of time above, the dale oldie event or default after which the designated period begins to run is not included in the period; the last day of Ibe period is included, unless it falls on a weekend or state holiday, in which event the period runs until 5:00 p.m on the net day that does not fall on a weekend or state holiday • • Page 1 of 1 Maunder, Thomas E (DOA) From: Paul_Figel @xtoenergy.com Sent: Friday, October 29, 2010 4:56 AM To: Maunder, Thomas E (DOA) Subject: Re: XTO MGS �23 and A33 -14 Ok. Paul "Maunder, Thomas E (DOA)" To Paul_Figel @xtoenergy.com, Scott_Griffith @xtoenergy.com, <tom.mau n der @alaska.gov> Greg_Duggin @xtoenergy.com cc Barney_Phillips @ xtoenergy.com, "Noble, Robert C (DOA)" 10/28/2010 06:15 PM <bob.noble @alaska.gov> Subject XTO MGS C42 -23 and A33 -14 Paul, et al, Due to some questions on other wells where similar annular pressure pilots and SSV's have been installed, the following clarification is provided. It is the Commission's expectation that when routinely tested (6 month interval) that the complete SVS system (pilot and valve) will be tested. In order to be sure of this expectation, the Administrative Approvals will likely be reissued with this clarification. Call or message with any questions. Tom Maunder, PE AOGCC 2/18/2011 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Friday, October 15, 2010 2:56 PM To:'Barney_Phillips@xtoenergy.com'; Paul_Figel@xtoenergy.com Cc: Noble, Robert C (DOA) Subject: RE: XTO Energy - C24-23 Rate and Pressure Monitoring Sept 2010 AIO # 9-007 Thanks Barney, Yes, please test the annular pilots with the safety valves. That will become pretty normal now.�� .� Call or message with any questions. Tom Maunder, PE (� AOGCC `—� ##'"- V -----Original Message----- I �� From: Barney_Phillips@xtoenergy.com[mailto:Barney_Phillips@xtoenergy.com] Sent: Friday, October 15, 2010 11:15 AM To: Paul_Figel@xtoenergy.com Cc: Maunder, Thomas E (DOA) Subject: RE: XTO Energy - C24-23 Rate and Pressure Monitoring Sept 2010 AIO # 9-007 Paul / Tom, We do not have another scheduled MIT due until 11/2011. Bob Noble (AOGC) is scheduled to be on board 11/11 and 11/12/2010 for 180 day cycle SVS tests. Would be happy to test these pilots while Bob is here for him to witness if you like. These pilots / actuators are easy to test and only requires shutting in injection for a short period of time. Barney Phillips barney_phillips@xtoenergy.com Platform A: 907-776-5241 Platform C: 907-776-5251 Paul Figel/MID/CTOC 10/08/2010 07:38 AM Barney, vow `AL1 "Maunder, Thomas E (DOA)" <tom.maunder@alaska.gov>, Barney Phillips/KEN/CTOC@CTOC To cc Subject RE: XTO Energy - C24-23 Rate and Pressure Monitoring Sept 2010 AIO # 9-007(Document link: Barney Phillips) 1 Please provide Tom with answer. Thanks, Paul "Maunder, Thomas E (DOA)" <tom.maunder@alas ka.gov> 10/08/2010 10:33 AM • • Paul—Figel@xtoenergy.com To cc Subject RE: XTO Energy - C24-23 Rate and Pressure Monitoring Sept 2010 AIO # 9-007 When is the next set of normal MITs scheduled out there? From: Paul_Figel@xtoenergy.com[mailto:Paul_Figel@xtoenergy.com] Sent: Friday, October 08, 2010 6:29 AM To: Maunder, Thomas E (DOA) Subject: RE: XTO Energy - C24-23 Rate and Pressure Monitoring Sept 2010 AIO # 9-007 Yes it was. It was Rule 6. We will combine Rule 5 at the same time. Paul "Maunder, Thomas E (DOA)" <tom.maunder@alaska.gov> 10/08/2010 08:50 AM Paul—Figel@xtoenergy.com To cc Subject RE: XTO Energy - C24-23 Rate and Pressure Monitoring Sept 2010 AIO # 9-007 2 Morning Paul, I thought the testing requirement was included in the administrative approval. Tom From: Paul_Figel@xtoenergy.com[mailto:Paul_Figel@xtoenergy.com] Sent: Fri 10/8/2010 4:38 AM To: Maunder, Thomas E (DOA); Barney_Phillips@xtoenergy.com Cc: Greg_Duggin@xtoenergy.com; Regg, James B (DOA); Scott_Griffith@xtoenergy.com Subject: RE: XTO Energy - C24-23 Rate and Pressure Monitoring Sept 2010 AIO # 9-007 Tom, The A33-14 has been SI since Aug. The wellhead work should be done by next week & then should be back on inj. Good idea for the testing. Barney Phillips is in charge of the SV & MIT testing. Paul "Maunder, Thomas E (DOA)" <tom.maunder@alaska.gov> 10/07/2010 06:00 PM To Paul_Figel@xtoenergy.com cc Scott_Griffith@xtoenergy.com, Greg_Duggin@xtoenergy.com, "Regg, James B (DOA)" <jim.regg@alaska.gov> Subject RE: XTO Energy - C24-23 Rate and Pressure Monitoring Sept 2010 AIO # 9-007 Thanks Paul. I presume the similar report for the Platform A well is coming. I don't know the SVS test schedule, however both pilots should be tested if possible when the safety valves are tested. Alternately, if there is an MIT the test can be accomplished then. Regards, Tom Maunder, PE AOGCC 3 • 0 From: Paul_Figel@xtoenergy.com[mailto:Paul_Figel@xtoenergy.com] Sent: Thursday, October 07, 2010 11:21 AM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: Scott_Griffith@xtoenergy.com; Greg_Duggin@xtoenergy.com Subject: RTO Energy - C24-23 Rate and Pressure Monitoring Sept 2010 AIO # 9-007 Attached is the Sept 2010 injection rate and wellhead pressure monitoring reports for the Middle Ground Shoal C24-23 as required by Administrative Approval AIO No. 9.007. The rate and pressure continue to indicate that there has been no change in the well's mechanical condition. The outer annulus pressure sensor was installed on Sept 26th that will SI the injection if the OA press hits 300 psi. Please contact me with any questions. Paul Paul Figel Engineering Manager XTO Energy Inc. Midland, TX Office: 432-620-6743 Cell: 432-553-5217 Fax: 432-687-0862 4 Regg, James B (DOA) From: Jeff_Gasch@xtoenergy.com Page 1 of 1 Sent: Monday, December 21, 2009 10:33 AM ~C1~- IZ,~z(~ To: Maunder, Thomas E (DOA); Regg, James 6 (DOA) i_ Cc: Scott_Landon@xtoenergy.com; Paul_Figel@xtoenergy.com; Scott_Griffith@xtoenergy.com; Greg_Duggin@xtoenergy.com Subject: C24-23 Rate and Pressure Monitoring 12-21-09 AIO # 9-007.x1s ~ Attachments: C24-23 Rate and Pressure Monitoring 12-21-09 AIO # 9-007.x1s ~" ~ ~ V~ ~~~ Attached is the November 2009 injection rate and wellhead pressure monitoring report for the Middle Ground Shoal C24-23 as required by Administrative Approval AIO No. 9.007. The rate and pressure continue to indicate that there has been no change in the well's mechanical condition. Please contact me with any questions. Thanks, Jeff Gasch Production Engineer XTO Energy Office # (432) 620-6742 Cell # (432) 638-7433 Fax # (432) 687-0862 ~~:~ J~~ ~ ~ Za~~ 12/21 /2009 XTO Energy - C24 -23 Rate and Pressure Monitoring Administrative Approval AIO No. 9.007 �_,Z 5000 - "'dm' CsgxTbg Annulus Pressure 500 "" Pressure Injection Rate (bbl /d) 450 4500 •Surface Casing Pressure 4000 400 a) y � d 3500 —,.— —..— — — — -- ---- -- -- -- -- -- -- - -- -- -- 350 0 c U 0 d I Y N 3000 300 !, C i • 2500 250 y a) a. < • 2000 200 c CI y a 1— N 1500 150 v ' U f6 1000 100 to 500 50 0 I 1 I t I I I 0 • 5/1/2010 5/5/2010 5/9/2010 5/13/2010 5/17/2010 5/21/2010 5/25/2010 5/29/2010 II C24 -23 Rate and Pressure Monitoring Administrative Approval AIO No. 9.007 Surf Injected Casing Annulus Injection Comments [bbl] [psig] [psig] [psig] 5/1/2010 263 20 3475 3550 5/2/2010 278 20 3475 3550 5/3/2010 301 20 3475 3550 5/4/2010 321 20 3475 3550 5/5/2010 324 20 3475 3550 5/6/2010 302 20 3475 3550 5/7/2010 321 20 3475 3550 5/8/2010 283 20 3475 3550 Down 3 hrs 5/9/2010 327 20 3475 3550 • 5/10/2010 328 21 3500 3550 5/11/2010 330 21 3500 3550 5/12/2010 343 22 3490 3550 5/13/2010 326 22 3550 3550 Down 1 hr 5/14/2010 245 20 3500 3550 Down 5 hrs - Power outage 5/15/2010 245 22 3450 3550 5/16/2010 303 22 3450 3550 5/17/2010 239 22 3450 3550 5/18/2010 246 22 3450 3550 Down 3 hrs 5/19/2010 301 22 3450 3550 Down 3 hrs 5/20/2010 345 22 3450 3550 5/21/2010 318 22 3450 3550 5/22/2010 326 22 3450 3550 5/23/2010 314 22 3450 3550 5/24/2010 328 22 3450 3550 5/25/2010 3 22 3450 3550 Down 24 hrs - DOT Pipeline testing 5/26/2010 0 22 3450 3550 Down 24 hrs - DOT Pipeline testing 5/27/2010 154 22 3450 3550 Down 12 hrs - DOT Pipeline testing 5/28/2010 308 23 3450 3475 1111 5/29/2010 333 24 3500 3500 5/30/2010 296 24 3500 3500 5/31/2010 304 24 3500 3500 • • s C r SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W 71h AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE 1907) 279 -1433 FAX (907) 276 -7542 ADMINISTRATIVE APPRO AL Area Injection Order 9.007 Revised Mr. Paul Figel Engineering Mana er Manager Energy 200 North Loraine, Suite 800 Midland, TX 79701 RE: MGS C24 -23 (PTD 1681070) Administrative Approval Revision Middle Ground Shoal (MGS) W. F, G Oil Pool Dear Mr. Figel: In accordance with Rule 6 of Area Injection Order ("A10 ") 09.000. on June 26. 2006 the Alaska Oil and Gas Conservation Commission (AOGCC or Commission) approved continued operation of MGS C24 -23 with tubing x inner annulus (TxIA) communication. AIO 9.007 restated observation and reporting obligations originally imposed in the Commission's letter of September 30, 1993 (copy attached). XTO has complied with the requirements and the operating information continues to demonstrate that the well structure remains competent and the injected fluids are being placed into the intended production intervals. All aquifers in the Middle Ground Shoal Field have been exempted [40 CFR 147.102 (b) (2) (iii)]. A recent review of the well operating conditions revealed that the surface injection pressure is 3500 psi which is 48% of the published minimum internal yield pressure (7240 psi) of the 7', 26 # /ft, N -80 production casing. The production casing is competent, however if a leak were to develop, the 10 -3/4 ", 40.5 #/ft, J -55 surface casing could fail when subjected to the surface injection pressure which calculates to 111% of published minimum internal yield pressure (3130 psi). To protect against overpressure and potential failure of the surface casing. the Commission now requires that XTO install engineering controls on the outer annulus (OA) of MGS C24 -23. With such controls 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 revised administrative approval to continue water injection only in MGS C24 -23 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 /0) pressures and injection rate daily; AIO 9.007Revised September 13, 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, A pressure test of the combined tubing and inner annulus (OMIT) is NOT required as stated in the Commission's letter dated September 20, 1993; 5. XTO shall perform a MIT -OA to 500 psi every 2 years; 6. Within 60 days of the effective date of this approval, 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 shall be performed in conjunction with production well pilots and safety valves; 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 to P '.s of DONE at Anchorage, Alaska • 4F to• p : ber 13, 2010. 1/A: �irr. or ► man Cathy Foerster Daniel T. Seamount • .� Y , VAN' Chair, Commissioner Com issioner 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 n 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 alter 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 on reconsideration. As provided in AS 31.05.080(b), "itlhe questions reviewed on appeal are limited to the questions presented to the Commission by the application for reconsideration." In computing a period of time above, the date of the event or default after which the designated period begins to run is not included in the period; the last day of the period is included, unless it falls on a weekend or state holiday, in which event the period runs until 5:00 p.m. on the next day that does not fall on a weekend or state holiday. • • Page 1 of 2 Maunder, Thomas E (DOA) From: Paul_Figel @xtoenergy.com Sent: Monday, September 13, 2010 5:44 AM To: Maunder, Thomas E (DOA) Subject: RE: XTO A33 -14 Press Comm Attachments: C24 -23 Wellhead.pdf Tom, Here's the set up for the wellhead. Paul "Maunder, Thomas E (DOA)" To <tom.maunder©alaska.gov> Paul_Figel @xtoenergy.com cc 09/10/2010 11:17 AM Subject RE: XTO A33 -14 Press Comm Thanks much. I misunderstood that there also would be some sort of relief capability in addition to the pilot and valve. With the drawing, I will be able to get the revision for C24 -23 out and then A33 -14 can soon follow. Thanks again for iterating with the information. Tom Maunder, PE AOGCC From: Paul_Figel @xtoenergy.com [mailto:Paul_Figel @xtoenergy.com] Sent: Friday, September 10, 2010 7:49 AM To: Maunder, Thomas E (DOA) Subject: RE: XTO A33 -14 Press Comm Tom, The pressure sensor will be located on the 10 -3/4" x 7" annulus. There is not a relief valve on the IA. It will be air automated valve (SSV) that is installed on the injection tbg that will close when the pressure sensor on the OA hits 300 psi that will halt injection. They are sending me a quick sketch this afternoon that should clarify this. 2/18/2011 Page 2 of 2 Paul "Maunder, Thomas E (DOA)" <tom.maunder @alaska.gov> To Paul_Figel @xtoenergy.com 09/09/2010 01:56 PM cc Subject RE: XTO A33 -14 Press Comm Hi Paul. I do appreciate what you all are doing here. I cannot tell you what to do and while we have been discussing diagnostic testing, any operation is XTO's decision to conduct. I understand your concerns and there is risk of junking the well. I believe I have sufficient information in order to write the AA. It appears that A33 -14 will essentially be similar to C24 -23 where it is not possible to set a WL plug for the combo MIT. C24 -23 has been unenterable for over 15 years. Only other item is regarding the "drawing ". It doesn't have to be fancy, but it would help to see how the installation will be set up. I know the SSV is on the flowline to the well and the pilot (set at 300 psi) is on the OA. I presume the actual relief valve will be on the IA. Is this a pop -off type relief or will the pilot activation also be in control here? Tom Maunder, PE AOGCC From: • - I_Figel @xtoenergy.com [mailto:Paul_Figel @xtoenergy.com] Sent: Thurs.: September 09, 2010 5:44 AM To: Maunder, Tho E (DOA) Subject: XTO A33 -14 • -- Comm Tom, Attached are the notes on how the well reacte. .en trying t. • eed down. We are concerned getting down with the tools if the tbg is parted. It might be better to drop : "i ' est tool downhole to pressure up on assuming there is not scale obstructing from going to bottom. Let m 'now ere is something else to discuss. Thanks, Paul Paul Figel Engineering Manager XTO Energy Inc. Midland, TX Office: 4 -.20 -6743 Cell: - - 553 -5217 .x: 432 - 687 -0862 2/18/2011 Qo7 q� �1 , , ., . S • � r fi� .. DNS i'�ur■•iA . .-=f t. {* ii, ,.- 'i .. .. . ,.:.,.....,.......,.,.:.. ..:.:„..........:-. : . . . PS „i Press.re S.-sor . ,.. ' ,....:,..... - 1 ( i,,,,i) - , - log .�,,. __..�. . . • , . . • FT .-....... • , ,... , ., • tom°) OIL 'TOOL: D I V SIOFJ- . . , SHELL V''ES . E Ar: P • • • C PLAT_ = LEG' 4 ;OND�tC1 p 32 WE LL' C- ^ 4- - .'", Fv-1 L_ F-",.:4 oEa 31"‘' . • . • . )413 — 1 2— 91 • , S \ltiC �. 4- ^.3 • . i Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Friday, August 13, 2010 2:12 PM To: 'Paul_Figel@xtoenergy.com' Subject: RE: Request for AA for MGS A33 -14 Importance: High ' - - Paul, I am looking at your request for administrative approval. For approvals with T x IA communication we look at the ratio of the injection pressure to the burst ratings of the production and surface casings. That ratio for the production casing is pretty critical since the IA is pressured up due to the communication. The ratio for the surface casing is important when failure of the production casing is concerned. For A- 33 -14, I calculate the following ratios based on the steady wellhead pressure submitted with the application. Production casing: 7 ", 23 #, N - at surface -- ratio = 3650 / 6340 = 57% Surface casing: 10 - 3/4" 40.5 #, J - 55 -- ratio = 3650 / 3130 = 117% I looked back at C -24 -23 (AIO 9.007) and the ratios are Production casing: 7 ", 26 #, N -80 at surface -- ratio = 3500 / 7240 = 48% Surface casing: 10 - 3/4" 40.5 #, J - 55 -- ratio = 3500 / 3130 = 111% I do not know if these calculations were made when AIO 9.007 was approved. There are other approvals out there (in other fields) where the production casing pressure ratio is about 60%, however I am not aware of any wells with approvals where the surface casing ratio exceeds 100% of published burst. The recent practice, where repair /workover is not planned and the production pressure ratio is around 60 %, is to require a pressure pilot be installed on the outer annulus with the intent to halt injection should the pressure threshold be exceeded. Please get back to me as soon as you can regarding the pressure situation on both wells. Tom Maunder, PE AOGCC Original Message From: Paul_Figel @xtoenergy.com [mailto:Pau1_Figel @xtoenergy.com] Sent: Friday, August 13, 2010 9:04 AM To: Maunder, Thomas E (DOA) Subject: RE: Request for AA for MGS A33 - Thanks, Tom. Paul Figel Engineering Manager XTO Energy Inc. Midland, TX Office: 432 - 620 -6743 Cell: 432 - 553 -5217 Fax: 432 - 687 -0862 "Maunder, Thomas E (DOA)" <tom.maunder @alas To 1 • • Page 1 of 2 Maunder, Thomas E (DOA) From: Paul_Figel @xtoenergy.com Sent: Friday, September 03, 2010 10:41 AM To: Maunder, Thomas E (DOA) Cc: Greg_Duggin @xtoenergy.com; Scott_Griffith @xtoenergy.com Subject: RE: XTO Energy - C24 -23 Rate and Pressure Monitoring Aug 2010 AIO # 9 -007 Greg - Can you provide this? Paul "Maunder, Thomas E (DOA)" To <tom.maunder @alaska.gov> Paul_Figel @xtoenergy.com cc Greg_Duggin @xtoenergy.com, Scott_Griffith@xtoenergy.com 09/03/2010 01:40 PM Subject RE: XTO Energy - C24 -23 Rate and Pressure Monitoring Aug 2010 AIO # 9- 007 Thanks Paul. When possible, can someone provide a diagram of how all this will be assembled? Thanks, Tom Maunder, PE AOGCC From: Paul_Figel @xtoenergy.com [ mailto :Paul_Figel @xtoenergy.com] Sent: Friday, September 03, 2010 10:34 AM To: Maunder, Thomas E (DOA) Cc: Greg_Duggin @xtoenergy.com; Scott_Griffith @xtoenergy.com Subject: RE: XTO Energy - C24 -23 Rate and Pressure Monitoring Aug 2010 AIO # 9 -007 Tom, Here's the data A33 -14. I was told we have the SSV valves for A33 -14 & C24 -23 but the press relief valves were 2 weeks out. They thought we should have everything installed before the end of the month. They were going to get you pictures once completed for both wells. Paul Figel Engineering Manager XTO Energy Inc. Midland, TX Office: 432 - 620 -6743 2/18/2011 • Page 2 of 2 Cell: 432 - 553 -5217 Fax: 432 - 687 -0862 "Maunder, Thomas E (DOA)" <tom.maunder©alaska.gov> To Paul_Figel @xtoenergy.com, "Regg, James B (DOA)" 09/03/2010 10:41 AM <jim.regg @alaska.gov> cc Scott_Griffith @xtoenergy.com, Greg_Duggin @xtoenergy.com Subject RE: XTO Energy - C24 -23 Rate and Pressure Monitoring Aug 2010 AIO # 9 -007 Thanks Paul. Do you have similar information for A33 -14? I am working to revise AIO 9.007 and the new AA for A33 -14. How goes the schedule for the pilots and SD valves? Tom Maunder, PE AOGCC From: Paul_Figel @xtoenergy.com [mailto:Paul_Figel @xtoenergy.com] Sent: Friday, September 03, 2010 6:46 AM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: Scott_Griffith@xtoenergy.com; Greg_Duggin @xtoenergy.com Subject: XTO Energy - C24 -23 Rate and Pressure Monitoring Aug 2010 AIO # 9 -007 Attached is the Aug 2010 injection rate and wellhead pressure monitoring reports for the Middle Ground Shoal C24 -23 as required by Administrative Approval AIO No. 9.007. The rate and pressure continue to indicate that there has been no change in the well's mechanical condition. Please contact me with any questions. Paul Figel Engineering Manager XTO Energy Inc. Midland, TX Office: 432 - 620 -6743 Cell: 432 - 553 -5217 Fax: 432 - 687 -0862 2/18/2011 XTO Energy - C24 -23 Rate and Pressure Monitoring iiims•CsgxTbg Annulus Pressure Administrative Approval AIO No. 9.007 — Injection Pressure 350 .'Injection Rate (bbl /d) —Surface Casing Pressure 300 4500 — m • z 250 - Ab cc E 4000 0 a 0 c d o •� Y 200 m • c o8 3500 '_° y d 3 —150 rn c ca Q U d H 3000 — 100 co U • 2500 50 2000 0 1/1/2010 1 /8/2010 1/15/2010 1/22/2010 1/29/2010 XTO Energy - C24 -23 Rate and Pressure Monitoring -rliCs Annulus Pressure Administrative Approval AIO No. 9.007 )(m-Injection Pressure Injection Rate (bbl /d) - 500 e Surface Casing Pressure — 450 4500 - 400 • 0) - 350 m 4000 0 o_ o - 300 :a ittabiA. A I US 3500 — — �� i — -` �_, 250 G) N a` c c - 2 00 ., Q U a1 e) H 3000 a) 150 0 - 100 2500 I - 50 2000 1 1 0 12/1/2009 12/8/2009 12/15/2009 12/22/2009 12/29/2009 TO Energy - C24-23 Rate and Pressure Monitoring -~CsgxTbg Annulus Pressure', Administrative Approval AIO No. 9.007 ~ ~~Injection Pressure ~,~~ _ - --- 400 ~~Injection Rate (bbl/d) (Surface Casing Pressure 350 4500 d 300 ~ ~ ~ ~ ~ ~ 4000 c ~ 250 D 'c (~,~ d • otS ~ ~ otS 3500 L 200 vyi N a` ~ ~ o' c Q 150 ~ rn ~ ~ 3000 x a~ ~ ~ v 100 2500 50 0 2000 ~ 11 /1 /2009 11 /8/2009 11 /15/2009 11 /22/2009 11 /29/2009 • • CsgxTbg Annulus 8~ Injection Pressure °o o °o °o °o °0 0 1 /1 /2009 1 /15/2009 1 /29/2009 2/12/2009 2/26/2009 3/12/2009 3/26/2009 4/9/2009 4/23/2009 5/7/2009 5/21 /2009 6/4/2009 6/18/2009 7/2/2009 7/16/2009 7/30/2009 8/13/2009 8/27/2009 9/10/2009 9/24/2009 10/8/2009 10/22/2009 11 /5/2009 11 /19/2009 12/3/2009 12/17/2009 12/31 /2009 ~ ~ ~ C7 ~ ~ ~ cQ ~ o' o' ~ m ~ ~ ~ ai ~ N ~ _~~°~~ ~ ~ ~ ~ y a ~ cn m c m o ~ N w ~ cn rn o °o °o °o °o °o Surface Casing Pressure & Injection Rate X O rn D~ Q ~ ~_ ~ 3~ ~ ~~ ~ N rt ~ C' N ~D W a ~ a ~ O ~ ~ Q ~ ~ ~ N Z N O ~ cs, ~ o O ~ ~ O ~~ (Q • s • • Page 1 of 1 Maunder, Thomas E (DOA) From: Jeff Gasch@xtoenergy.com Sent: Tuesday, November 24, 2009 7:58 AM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: Scott_Landon@xtoenergy.com; Paul_Figel@xtoenergy.com; Scott_Griffith@xtoenergy.com; Greg_Duggin@xtoenergy.com Subject: C24-23 Rate and Pressure Monitoring 11-24-09 AIO # 9-007.x1s ~~~---~„w ,~ Attachments: C24-23 Rate and Pressure Monitoring 11-24-09 AIO # 9-007.x1s ' Y"t ~b~-~~~ i~ia~ Attached is the October 2009 injection rate and wellhead pressure monitoring report for the. Middle Ground Shoal C24-23 as required by Administrative Approval A10 No. 9.007. The rate and pressure continue to indicate that there has been no change in the well's mechanical condition. Please contact me with any questions. Thanks, Jeff Gasch Production Engineer XTO Energy Office # (432) 620-6742 Cell # (432) 638-7433 Fax # (432) 687-0862 ~" a ~~A ~~~~ ~~~ ~ ~~ Sti 11 /24/2009 PTO Energy - C24-23 Rate and Pressure Monitoring -~-csgXrbg Annulus Pressure ~I Administrative Approval AIO No. 9.007 ~N~Inior#inn Drocciiro ~-Injection Rate (bbl/d) ~-Surface Casing Pressure 4500 d 3 ' ~ 4000 a C 0 r V d ~ C ~tS 3500 3 C C a a1 ~ 3000 x a~ V 2500 2000 10/1 /2009 10/8/2009 10/15/2009 10/22/2009 10/29/2009 350 300 250 c 0 U d _C 200 ,~ d a 150 c y R U d v 100 in 50 • • CsgxTbg Annulus 8~ Injection Pressure °o o °o o °o °o °o 1 /1 /2009 1 /15/2009 1 /29/2009 2/12/2009 2/26/2009 3/12/2009 3/26/2009 4/9/2009 4/23/2009 5/7/2009 5/21 /2009 6/4/2009 6/18/2009 7/2/2009 7/16/2009 7/30/2009 8/13/2009 8/27/2009 9/10/2009 9/24/2009 10/8/2009 10/22/2009 ~ ~ ~ n ~ ~ ~ co ~ o' o' ~ m ~ ~ ~ ~ ~ D ~ ~ vii c ~ ~ ~ ~ (D N m ~ Q ~ m ~' c m o ~ N w ~ cn rn °o °o °o °o °o °o Surface Casing Pressure & Injection Rate 0 rn D~ Q ~ ~• K ~ n ~ ~ =+ ,~ ~' N ~D W ~ ~ ~ ~D ~ Q D ~ ON Z N O ~ co ~ O o O ~ ~ ~r O ~_ ~~ • ~ ~ Page 1 of 1 Regg, James B (DOA) ~~ ~ ~'~~ From: Jeff_Gasch@xtoenergy.com ~; ~~ , ~~ ~ ~, Sent: Wednesday, September 23, 2009 8:02 AM ;\~~ ~l ~~~ ~~' To: Maunder, Thomas E(DOA); Regg, James B(DOA) Cc: Scott_Landon@xtoenergy.com; Paul_Figel@xtoenergy.com; Scott_Griffith@xtoenergy.com; Greg_Duggin@xtoenergy.com Subject: XTO Energy - C24-23 Rate and Pressure Monitoring AIO # 9-007 Attachments: C24-23 Rate and Pressure Monitoring 9-10-09 AIO # 9-007.x1s Attached is the August 2009 injection rate and welihead pressure monitoring report for the Middle Ground Shoal C24-23 as required by Administrative Approval AIO No. 9.007. The rate and pressure continue to indicate that there has been no change in the well's mechanica! condition. Please contact me with any questions. Thanks, Jeff Gasch Production Engineer XTO Energy Office # (432) 620-6742 Cell # (432) 638-7433 Fax # (432) 687-0862 ~~,~i~i~~~~~ :~':,'~ ~, ~'' ~~~~ 9/23/2009 /~--~-:"i' ` ~ I~~,~iG7 ~ XT[l Fnarnv _('_7d_~3 Rata anrl Prp~sure Monitorina v ~ - ~~CsgxTbg Annulus Pressure Administrative Approval A10 No. 9.007 ~-~~Injection Pressure ------- -~--~ ---~- ~! I-•~Injection Rate (bbl/d) i -- - ^ -- ~~Surface Casing Pressure i 4500 d ~ ~ w ~ ~ 4000 a c O Y V^, W . ~ ~S 3500 ~ ~ ~ C C Q rn ~ 3000 x rn N U 2500 2000 ~ 8/1 /2009 8/8l2009 8/15/2009 8/22/2009 8/29/2009 400 350 300 d ~a ~ c 0 250 ~ 'c W Q~ L ~ 2~~ ai d ~ a rn c .y 150 ~ d ~ ~ ~ ~ 100 I 50 0 i . A ,~tT ~ ~ I b~l~ lG ~ XTO Energy - C24-23 Rate and Pressure Monitoring Administrative Approval AIO No. 9.007 m ~ y N d a` C O :_~ U d .~ ~ ~ ~ ~ C C Q rn ~ ~ x rn ~ U 5000 4500 4000 3500 3000 2500 600 500 d ~a ~ C 4~~ ~ U a~ 'c ~ ~ G7 7 300 n d ~ a w c .N m U 200 °; ~v ~ ~ ~ 100 2000 ~\~0~0 ~\~0~~ ~\~0~0 ~~o~~ ~\~0~~ ~\~o~~ ~\~o~~ ~\ ~~~ ~~~ ti ti~ ~~~ ~~~ ~ 0 O°~ O°~ O°~ O°~ O°~ O°~ O°~ O°~ O°~ O°' O°' ~O ,~O ~O ,LO ,ti0 ~O ,~O ,ti0 ,LO ~O ~O ~~~~ \~,~~ ~~~ \~,~\ ~~p~\ \~~\ ~~~,\ \~~\ \~~\ \~~\ \~~\ D~ h 0 1 '1 ~ ~ • • • Page 1 of 1 Regg, James B (DOA) From: Jeff Gasch@xtoenergy.com Sent: Friday, April 03, 2009 7:30 AM ~ ~~ 13~ 0 To: Maunder, Thomas E (DOA); Regg, James B (DOA) ',\~~ Cc: Scott_Landon@xtoenergy.com; Paul_Figel@xtoenergy.com; Scott_Griffith@xtoenergy.com; Greg_Duggin@xtoenergy.com Subject: XTO Energy - MGS C24-23 Rate and Pressure Monitoring AIO # 9-007 ~ ~ ,,, i (~ f~ Attachments: C24-23 Rate and Pressure Monitoring 4-3-09 AIO # 9-007.x1s 4 `J Attached is the March 2009 injection rate and wellhead pressure monitoring report for the Middle Ground Shoal C24-23 as required by Administrative Approval AIO No. 9.007. The rate and pressure continue to indicate that ~% ~th-e- ryas been no change in the well's mechanics con ition. r-----~ Please contact me with any questions. Thanks, Jeff Gasch Production Engineer .~ ~ ~ ,~ XTO Energy ;_.~.~,~,i • ASR ~ g ~.4~~ Office # (432) 620-6742 Cell # (432) 638-7433 Fax # (432) 687-0862 4/3/2009 TO Energy - C24-23 Rate and Pressure Monitoring '~~CsgxTbg Annulus Pressure Administrative Approval A1O No 007 9 . . '-~E-Injection Pressure --~-Injection Rate (bbl/d) -~-Surface Casing Pressure 4500 m L y N ~ 4000 a c O V d . ~ C aS 3500 N S C C Q F 3000 X Q1 N U 2500 2000 3/1 /2009 3/8/2009 3/15/2009 3/22/2009 3/29/2009 400 350 300 250 200 150 d t+ c 0 .U d ~c a~ m y y d a rn c .N ca U a> v ~v 3 100 50 0 • CsgxTbg Annulus 8~ Injection Pressure N O O O 7/1 /2006 8/1 /2006 9/1 /2006 10/1 /2006 11 /1 /2006 12/1 /2006 1 /1 /2007 2/1 /2007 3/1 /2007 4/1 /2007 5/1 /2007 6/1 /2007 7/1 /2007 8/1 /2007 9/1 /2007 10/1 /2007 11 /1 /2007 12/112007 1 /1 /2008 2/112008 3/1 /2008 4/1 /2008 51112008 6/1 /2008 7/1 /2008 8/1 /2008 9/1 /2008 10/1 /2008 11 /112008 12/1 /2008 1 /1 /2009 2/1 /2009 3/1 /2009 4/1 /2009 cNi, o cn o can o O O O O O O Surface Casing Pressure & Injection Rate m D~ a~ ~• ~G ~ n ~ N ~' N ~D W ~ ~ ~ ~ O >,J < ~ Sv G. D ~ N Z N O ~ t0 ~ o O ~ ~ O ~~ (~ o ~ N w ~ cn rn 00 °0 00 °0 00 °o w~.. • • Regg, James B (DOA) From: Jeff_Gasch@xtoenergy.com ~ Sent: Monday, October 06, 2008 7:51 AM ~2~ ~ ! ~>~`~ ~~.~'-~ To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: Scott_Landon@xtoenergy.com; Paul_Figel@xtoenergy.com; Scott_Griffith@xtoenergy.com; Greg_Duggin@xtoenergy.com Subject: XTO Energy - MGS C24-23 Rate and Pressure Monitoring AIO # 9-007 Attachments: C24-23 Rate and Pressure Monitoring 10-6-08 AIO # 9-007.x1s P~ i~c~-- ~ 0 7 Attached is the September 2008 injection rate and wellhead pressure monitoring report for the Middle Ground Shoal C24-23 as required by Administrative Approval AIO No. 9.007. The rate and pressure continue to indicate .~ ,. that there has been no change in the well's mechanical condition. Please contact me with any questions. Thanks, Jeff Gasch Production Engineer XTO Energy Office # (432) 620-6742 Cell # (432) 638-7433 Fax # (432) 687-0862 ~ ~~ E~~uf 10/6/2008 XTO Energy - C24-23 Rate and Pressure Monitoring ~--~-CsgxTbg Annulus Pressure Administrative Approval A1O No. 9.007 ~~~Injection Pressure ~"'~~Injection Rate (bbl/d) '~~Surface Casing Pressure 400 350 I 4500 N 4000 i a c 0 ~, 'c off 3500 N _3 7 c ~ a ~ 3000 U 2500 2000 9/1 /2008 9/8/2008 9/15/2008 9/22!2008 • 300 0 250 ~ ! 200 w d a C 150 v ' ~ • 10C 50 - 0 9/29/2008 N O O O 7/1 /2006 8/1/2006 9/1 /2006 1011 /2006 11 /1 /2006 12/1 /2006 1 /1 /2007 2/1 /2007 3/1 /2007 4l1 /2007 5/1 /2007 6/1 /2007 7/1/2007 8/1 /2007 9/1/2007 10/1 /2007 11 /1 /2007 12/1 /2007 1/1/2008 2/1/2008 3/1/2008 4/1 /2008 5/1!2008 6/1/2008 711 /2008 8/1/2008 9f112008 10!112008 CsgxTltig Annulus 8 Injection Pressure N W W .p A (77 O O O O O O ~ ~ ~ W .® rro ~ ~ ~ r°~ ~ ~~~~e Cas6u~g ~'~essa~re & ~~e~ect~a~ ~aae i ~ n c~ x co D ~ ~ c c v ~ N ~ sD _m ~ ~ ~. ~ ~ e y. n ~ ~ ~ ~ ~ N ~p 49 ~ ~ ~ ~ O ~ < ~ >y ~. o ~ f u~ y O c=~D - ~p i ~l ~ °~. O 0 • • From: Jeff_Gasch@xtoenergy.com ''~` ~'~ ~_~~ Sent: Friday, June 06, 2008 6:41 AM ,. ~` =i i ~ ~ u- ~~~ To: Maunder, Thomas E (DOA); Regg, James B (DOA) ~ ` Cc: Scott_Landon@xtoenergy.com;Paul_Figel@xtoenergy.com; Scott_Griffith@xtoenergy.com; Greg_Duggin@xtoenergy.com Subject: C24-23 Rate and Pressure Monitoring AIO # 9-007.x1s Attachments: C24-23 Rate and Pressure Monitoring 6-6-08 AIO # 9-007.x1s `' ~: i. C24-23 Rate and Pressure Monit... Attached is the May 2008 injection rate and wellhead pressure monitoring report for the Middle Ground Shoal C24-23 as required by Administrative Approval AIO No. 9.007. The rate and pressure continue to indicate that there has been no change in the well's mechanical condition. Please contact me with any questions. (See attached file: C24-23 Rate and Pressure Monitoring 6-6-08 AIO # 9-007.x1s) Thanks, Jeff Gasch Production Engineer XTO Energy Office # (432) 620-6742 Cell # (432) 638-7433 Fax # (432) 687-0862 ~~P~1N~~ Fuca ~ ~ 200 1 5000 XTO Energy - C24-23 Rate and Pressure Monitorincr Administrative Approval A1O No. 9.007 ~CsgxTbg Annulus Pressure Injection Pressure ~~Intection Rate (bbl/d) ~~'Surface Casing Pressure 4500 ~ 50U _ • as 4000 a c 0 m .~ c ~s 3500 c C Q ~ 3000 j ~ i a~ w 2500 2000 5/1 /2008 ~~ 4oa ~: ~a 3 300 ~ a~ a c .y c6 (S 200 a~ • 100 o 5/8/2008 5/ 15/2008 5/22/2008 5/29/2008 • a;aa uoi;aafdi~ '8 a~nssard Sa~esr:;~ aae~ang 0 0 0 0 0 ~ ~ 0 0 0 0 0 c ~L 0 ~_+ ,~ ~ O 0 ~ ~ i O ~Z N L O aa_ ~ ~ C t0 O ~ Q. ~ Q ~a M ~ N ~ t, N U N ~ ~__ ~.~ m ~ ~ ~ = Q a W d i O ~ °' 1 3~1 ~- ~ a ~ ~ a o ~ o < ~a a U ~ ~ 0 0 O 0 800Z/ 6/9 aooz/ ~i5 sooz/L/b soot/ ~/E sooz/ uz $~~z/ ~/ L LOOZ/ 6/Z L LOOZ/L/L L LOOZ/ L/0 L LOOZ/ l/6 LOOZ/6/8 LOOZ/ 6/L LOOZ/ 6/9 LOOZ/ L/5 LOOZI 6/b LOOZ/ l/E LOOZ/ 6/Z LOOZ/ L/ L 900Z/ 6/Z l 900Z/ L/ L 4 900Z/ L/0 L 900Z/ 6/6 900Z/ L/8 900Z/ 6/L 0 0 0 N °o °o °o o ~o ~ ~ M OM N a~nssaad uoi;~afu~'8 sn~nuud 6glx6s~ XTO Energy - MGS C24-23 Monitoring Report - December 2006 -... . . \ l.!~ - I 0 1 Attached is the December 2006 injection rate and wellhead pressure monitoring report for the Middle Ground Shoal C24-23 as required by Administrative Approval AlO No. 9.007. The rate and pressure continue to indicate that there has been no change in the well's mechanical condition. Please contact me with any questions. (See attached file: C24-23 Rate and Pressure Monitoring 01-01-07 AlO # 9-007.xls) Thanks, Jeff Gasch Production Engineer XTO Energy Office # (432) 620-6742 Cell # (432) 638-7433 Fax # 432 687-0862 ~~ED FEB 2 (; Z007 . . Content-Type: application/msexcel C24-23 Rate and Pressure Monitoring 01-01-07 AIO # 9-007.xls. _,'. .."..- '. ,-' Content-Encoding: base64 1 of 1 1/3/20072:04 PM 4500 ! s ::::I In 1\1 In a: ! 4000 a.. I>iS f :::¡ cð 3500 II! !II In f ..2 Q. ::::I C C « (II 3000 u ~ :::¡ ro 5000 2500 2000 2/1/2006 12/8/2006 5/2006 ! ::::I In In ø ... a.. IfI U ~ ::I ro 5000 Annulus Pressure Pressure Rate Pressure I>iS cð In :::I :¡ C C « XTO Energy - MGS C24-23 Monitoring Report - November 2006 . . Attached is the November 2006 injection rate and wellhead pressure monitoring report for the Middle Ground Shoal C24-23 as required by Administrative Approval AIO No. 9.007. The rate and pressure continue to indicate that there has been no change in the well's mechanical condition. Pleasè contact me with any questions. (See attached file: C24-23 Rate and Pressure Monitoring 12-01-06.xls) Thanks, Jeff Gasch Production Engineer XTO Energy Office # (432) 620-6742 Cell # (432) 638-7433 Fax # 432 687-0862 Content-Type: applicationlmsexcel Rate and Pressure Monitoring 12-01-06.xls Content-Encoding: base64 ~t~1\HNED r. I~ ¿U fJf: (4 '....___ 1 of 1 12/4/2006 8:47 AM in AIO Annulus Pressure 5000 Pressure Rate Pressure 4500 e s :s IJ <I:! IJ Œ: e 4000 c. 06 e ::::I ~ 3500 III III IJ e ..2 CI. :s c c 0( II» 3000 ~ ~ ::I fJ) 2500 00 2000 11/1/2006 11/8/2006 1115/2006 1 XTO Energy - MGS C24-23 Monitoring Rei . Attached is the October 2006 injection rate and wellhead pressure monitoring report for the Middle Ground Shoal C24-23 as required by Administrative Approval AlO No. 9.007. The rate and pressure continue to indicate that there has been no change in the well's mechanical condition. Please contact me with any questions. (See attached file: C24-23 Rate and Pressure Monitoring 11-01-06.xls) Thanks, Jeff Gasch Production Engineer XTO Energy Office # (432) 620-6742 Cell # (432) 638-7433 Fax # 432 687-0862 Content-Type: application/msexcel Rate and Pressure Monitoring 1l-Ol-06.xls Content-Encoding: base64 . r", .'.'. ."u- ffi\~"!:M~r::Uj .\;; ~/j\" . P. p~ \J {: 1 of 1 11/2/20062:38 PM 5000 Pressure Rate Pressure Q> ... :::¡ IIÞ IIÞ Q> ... Q. 400 500 ~ 3000 2500 0/15/2006 1 .s 1\1 0::: IIIJ f :::¡ IJ IJ I!! Q. 200 IJ u ~ :::¡ IIÞ XTO Energy - MGS C24-23 Monitoring Report . . Attached is the September monitoring report for the Administrative Approval AlO No. 9.007. there has been no change 2006 injection rate and wellhead pressure Middle Ground Shoal C24-23 as required by The rate and pressure continue to indicate that in the well's mechanical condition. Please contact me with any questions. (See attached file: C24-23 Rate and Pressure Monitoring 10-3-06.xls) Thanks, Jeff Gasch Production Engineer XTO Energy Office # (432) 620-6742 Cell # (432) 638-7433 Fax # (432) 687-0862 Content-Type: application/msexcel C24-23 Rate and Pressure Monitoring lO-3-06.xls Content-Encoding: base64 1 of 1 ~r\"~-~. ~\ '"' ~~J 11/2/2006 2:48 PM ~ 3500 ~ :::I III IJ 011 .. Q. 3000 011 U ~ :::I IIÞ 2000 9/1/2006 o XTO Energy - MGS C24-23 Monitoring Report . . Attached is the August 2006 injection rate and wellhead pressure monitoring report for the Middle Ground Shoal C24-23 as required by Administrative Approval AlO No. 9.007. The rate and pressure continue to indicate that there has been no change in the well's mechanical condition. Also, please note that the July 2006 annulus pressure has been updated. Please contact me with any questions. (See attached file: C24-23 Rate and Pressure Monitoring 9-5-06.xls) Thanks, Jeff Gasch Production Engineer XTO Energy Office # (432) 620-6742 Cell # (432) 638-7433 Fax 432 687-0862 Rate and Pressure Monitoring Content-Type: application/msexcel Content-Encoding: base64 1 of 1 ~t\~~~\\ " \rt:(a~ 11/2/2006 2:48 PM ~ in o 8/1/2006 8/1 - .s III 0:: IIIJ Re: XTO Energy - MGS C24-23 Monitoring ¡rt . See attached file. Let me know if there are any problems. (See attached file: C24-23 Rate and Pressure Monitoring.xls) Thanks, Jeff Gasch Production Engineer XTO Energy Office # (432) 620-6742 Cell # (432) 638-7433 Fax # (432) 687-0862 Thomas Maunder <tom maunder@admi n.state.ak.us> To 08/02/2006 04:00 PM ,Jeff Gasch@xtoenergy. corn cc Jim Regg <jirn regg@admin.state.ak.us> ........_mmm._.......m..m...mmmmm.mmmm·Sub j e c t Re: XTO Energy - MGS C24-23 Monitoring Report Jeff, On the excel sheet, is it possible to also include the graph that you sent hard copy? I may not have been clear about that in my earlier message. Thanks, Tom Maunder Jeff Gasch@xtoenergy.com wrote, On 8/2/2006 12:52 PM: Attached is the July 2006 injection rate and wellhead pressure monitoring report for the Middle Ground Shoal C24-23 as required by Administrative Approval AlO No. 9.007. The rate and pressure continue to indicate that there has been no change in the well's mechanical condition. Please contact me with any questions. (See attached file: C24-23 Rate and Pressure Monitoring.xls) Thanks, Jeff Gasch Production Engineer t)t'\~~-~. , ~ CðH) 11/2/2006 2:47 PM lof2 Re: XTO Energy - MGS C24-23 Monitoring ¡rt XTO Energy Office # (432) 620-6742 Cell # (432) 638-7433 Fax # (432) 687-0862 . Rate and Pressure Content-Type: applicationlmsexcel Content-Encoding: base64 2of2 11/2/20062:47 PM 5000 Annulus Pressure Pressure Rate 4500 500 Q> ... .s :::¡ IIÞ III IIÞ 0:: e 4000 Q. IIIJ 2! ::::! ~ 3500 IJ IJ IIÞ I!! .a Q. :::¡ C C « IJ 3000 u ~ ::¡ IIÞ 7/1/2006 7/8/2006 Re: C24-23 (168-107) . . Paul, I did not have any handle on the specific rates for this well. Thanks for the clarification, flowing back clearly does not look to be viable. Looks like you have multiple issues with this well. It is probably appropriate for XTO to request an AA under the injection order to keep the well in operation. An administrative approval is the mechanism that the Commission is using to allow injection wells to continue operation with an integrity loss. This process replaces what was previously approved with a Sundry. We look forward to receiving your application. Call or message with any questions. Tom Maunder, PE AOGCC Paul Figel(á}xtoenergy.com wrote, On 5/23/2006 2:03 PM: Tom, I visited with Tom Reese on trying to backflow while we cut scale. We both feel this would be in effective. The well is taking about 400 BWIPD @ 3500 psi, which is ±1/4 BPM. The well does not flow back hard w/ a sustained energy. Therefore, we would lose energy pretty quick & have only 1 cp water trying to carry chips of scale out of the well. The 1.70" gauge ring that couldn't get past 1250' in a 2.44" ID in 8500' of tbg will take a lot effort getting to full drift ID. The easiest way is to spend about $300k for a coil tbg cleanout. However, Tom reminded me that he believes the tbg is parted between 4,000 - 5,000' and therefore, coil tbg may not make it to bottom depending on the assumption of parted tbg. So far we know the 7" longstring has good integrity since there is only 14 psi on the 10-3/4" surface csg. Since this morning, I spoke with my reservoir manager. He's wanting us to run the economics on fixing versus P&A. This well supports 2 wells making combined 50 BOPD. Fixing looks complicated with 2 packers in the hole w/a fish on top of the upper pkr. (See attached file: C24-23 Current WBD 2-10-05.doc) Would it be possible to continue injecting while keeping a close eye on the Surface Casing press until we get a game plan & act on it? We would obviously shut down injection as soon as the press communicated to the surface csg. In answer to your other question on rig activity for 2006, for the time being, it looks like the $5 million I spent repairing All-13RD WIW & A41A-11LN WIW & coil tbg stimulating A34-11LS2 & C21A-23 is it for '06. They slashed wells from the budget in every division due to the drilling cost that is expontial. Our drilling contract goes up every 30 days & to stay with in our budget, wells are getting cut. Let me know if you need more info. Paul ðc-\",Q ~~ \ 1(tc.c~~ 11/2/2006 2:45 PM 1 off"? - -_ , - -- ,> _ _ c®r~s~~t~~xa®~ c®z~ssa®.le~ FRAAIK H. MURKOlMSKI, GOVERflIOR 333 W. 7`" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 AD~tiIINISTRATIVE APPROVAL NO. AI® 9.007 Mr. Jeff Gasch Production Engineer XTO Energy 200 North Loraine, Suite 800 iVlidland, TX 79701 RE: N1GS C24-23 (PTD 168-107) Request for Administrative Approval Dear ~Ir. Gasch: ~~~ a a~ a s 20~~ On June 1, 2006 XTO Energy ("XTO"} requested an administrative approval under Rule 6 of Area Injection Order ("AIO") 9 to allow continued water injection in Middle Ground Shoal ("IVIGS") well C24-23. The Alaska Oil and Gas Conservation Commission ("Commission") GRANTS XTO's request for WATER ONLY service, as detailed below. C24-23 was originally reported to have tubing x inner annulus ("T x IA") pressure communication in June 1992. The prior operator, Shell Western E&P ("Shell") obtained sundry approval to keep the well in operation with integrity being demonstrated by running diagnostic logs every 2 years. Due to scale deposition and the Loss of wireline tools in the wellbore, it was not possible to log the well and Shell sought approval to demonstrate continued integrity by monitoring injection rates and pressure daily and reporting the information to the Commission monthly. EPA recognizes pressure monitoring as an acceptable method of demonstrating continued integrity and the Commission approved Shell's request by letter dated September 20, 1993. The well has been operating since then according to the terms of the 1993 approval. It is still not possible to iog the well and XTO is considering a workover of the well possibly in 2007 to regain access to the well and restore integrity. The Commission finds that C24-23 exhibits tw•o competent barriers to the release of well pressure, based upon monitoring results XTO has submitted in compliance with the September 20, 1993 approval. Accordingly, the Commission believes that the well's condition does not compromise overall well integrity- and will not result in an increased risk of movement of fluids outside the injection zone. Where freshwater is not affected, 20 AAC 25.40 gives the Commission authority to approve less stringent well integrity and operation requirements. • • .ADMNISTRAT'IVE APPROVAL AIO NO. 9.007 June 26, 2006 Page ? of 2 Per Rule 9 of AIO 6, the Commission hereby grants XTO's request to continue water injection in MGS C24-23 on the following conditions: 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; 3. XTO shall submit to the Commission a monthly report of well pressures and injection rates including any pressure bleed events; 4. XTO shall immediately shut in the well and notify the Commission upon any measurable change in the wells mechanical condition; and ~. After well shut in due to a change in the well's mechanical condition, Commission approval shall be required to restart injection. As provided in AS 31.0.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DONE at A,~chora~e, Alaska and dated June 26, 2006. The Alaska Oil and Gas Conservation Commission ~ ~ .~ p ~ ~~~' ~, K. rman Daniel T. Seamount, Jr. Cathy,'. Foerster Chairman Commissioner Commissioner \ ~ b~ .,~~ \ ` o ` Q ~~,~ ,4 tiJ a ~.. 4 •~J-. .i `\ ~ F~ 111,+,T1 ~12 .:~1 ... r:..,-r~. w"r-1.y'c~ `.7RyA1`R' .,~ •., Re: C24-23 (168-107) 2 Or! '5 . . Thomas Maunder <tom maunder@admi .... ·._.............._....___......._m...........___.............._...... .....___.._____....___......._..... n.state.ak.us> -------...-------..----...-.....-..-.---...-...-..----..-------.-.--_........-._.._.__....._..._-----------_..-_.....~_.._-_..........__...- To Paul Figel@xtoenergy.com OS/23/2006 10:11 AM cc Jim Regg .:<:.t~rJ1_~~9.9~~9:9:~~I.:1.:.§.t:::?:~~:.9:.J<::..:~§..? ' Tom Reese@xtoenergy.com, ~~~.~_º?:_~c:.h(~~.t:::g.~!!:~E.9Y...:!;_<2rJ1 ' Scott Griffith@xtoenergy.com Subject Re: C24-23 (168-107) Paul, You all know more about the well than we do. The only observation I make and that is what it is, (sorry for so many "is") is it not possible to flow the well to at least clean up any scale while doing the work? I don't know all the logistics on doing that or if the well would just die. Like I said, just an observation. I read your statement on the postponement of the C23-26 sidetrack to mean that there is presently no work planned on C platform. Tom Maunder, PE AOGCC Paul Figel@xtoenergy.com wrote, On 5/23/2006 6:19 AM: Sorry Tom, I dropped the ball on that follow up from last summer. Attached is the Daily Report for C24-23 for 7-18-05. As shown in the report, we attempted to do a temp survey but the pre-run with the drift ring was hitting a lot of scale in the tbg. Without being able to flow back the scale cuttings, as would be a producer, the temp survey job was called off due to the risk of getting the slickline tools stuck. I am waiting for a callback from my reservoir manager in FTW on the plans for the well. FTW notified me 2 weeks ago that my sidetrack on Platform C for SI well C23-26 WIW is postponed until 2007 Ql. Knowing these circumstances, do we have any options that you can suggest? Thanks, Paul (See attached file: C24-23 Report for Drift Run 7-18-05.doc) Paul Figel Engineering Manager 11/2/2006 2:45 PM . . Midland Morning Report Objective: Drift Run 1st Rept: 07/18/2005 7/18/05 All depths are WLM. RU WL & press tsted lubricator. RIH w/1. 70" gauge ring. Hit obstruction @ 1,226' & cut scale to 1,234'. POOH w/gauge ring, since no means to remove cuttings on injection well. RD WL. RWTI. (Objective was check tbg prior to RIH w/temp tool for AOGCC survey due to press communication on TCA. ) DWC: $ 0 ewC: $ 0 DMC: $ 0 CMC: $0 Re: C24-23 (168-107) ~7 ~O jof4 . . C24-23 (168-107) Paul, I realize that you might not be the one to message on this, but I think you will know who to send it to. What are your plans for this well? It has tubing x casing communication and the last note we exchanged in mid-March 2005 indicated that a temperature survey was planned with the possibility of applying for an Administrative Approval. Was the survey ever done? I cannot find anything in my email files of having received one. Thanks in advance for looking into this. Tom Maunder, PE AOGCC 11/2/20062:45 PM . 24" Conductor Casing @ 370' Surf Csg: 103/4",40.5 Ib, J55. Set @ 1830'. Cmt'd wI 1300 sx. Parted tbg @ 4000 -5000' Fish Longstring: 7" 26 & 29# N80. Set @ 9530'. Cmt wI 960 sx. PBTO: 9441' TO: 9555' . KB: 35' Water Depth: 73' MSL PLF 2-10-05 Tubing: 2-7/8",6.5#, L80 EUE 8rd Otis "X" Nipple @ 300' Otis "X" Nipple @ 7970' Baker "DB" Pkr (anchored seals) @ 8000' Baker "DB" Pkr wi 5' Seal Bore Ext. @ 8500' Otis "XN" Profile Nipple @ 8530' Baker Wireline Re-entry guide @ 8532' GN-GO: 8108'-8140' MO 7972'-8003' TVO GR-GS: 8413'-8466' HC-HO: HC-HO: HO-HE: HE-HF: HI-HK: HI-HK: HK-HN: HN-HR: HN-HR: HR-HZ: HR-HZ: 8702'-8709' 8720'-8758' 8766'-8775' 8824'-8865' 8928'-8942' 8955'-8967' 8985'-9110' 9128'-9185' 9198'-9278' 9312'-9333' 9355'-9440' 8273'-8326' 8560'-8567' 8578'-8615' 8623'-8632' 8681'-8721' 8784'-8798' 8811'-8823' 8841'-8965' 8983'-9040' 9053'-9132' 9166'-9187' 9209'-9293' Re: C24-23 Monitoring Report . . Jeff, It would be preferred if you could send the xls sheet. That gives us something to play with. You do not need to send any other hard copies, electronic is fine. In the message accompanying the spreadsheet you can include a statement similar to what you had in the letter. Also, in the plot you should include the well name (already have that in the title) and the AA applicable to the well. Would you mind sending the electrons for the July data? That would be appreciated. Call or message with any questions. Tom Maunder, PE AOGCC Jeff Gasch@xtoenergy.com wrote, On 8/2/2006 11:43 AM: Tom, It's no problem to send it electronically but I have a few questions. In the future should I only send it electronically? Do you want the excel spreadsheet where the data is kept or just a .pdf copy of the tabular data and plot? If the report is to only be sent electronically do I still need to send a similar cover letter addressed to you and Jim Regg? Thanks, Jeff Gasch Production Engineer XTO Energy Office # (432) 620-6742 Cell # (432) 638-7433 Fax # (432) 687-0862 SCANNE.D AUG 0 8 2005 Thomas Maunder <tom maunder@admi n.state.ak.us> To 08/02/2006 02:05 PM Jeff Gasch <jeff gasch@xtoenergy.com> cc Subject C24-23 Monitoring Report Jeff, We just got the monitoring report for C24-23. Is it possible to send that electronically? Paul was sending a similar report a while back. If you can, the report should be addressed to me and Jim Regg at jim regg@admin.state.ak.us. 10f2 8/7/2006 1 :45 PM . . ~TO ~~RGY l\LfG 200 North Loraine Suite 800 Midland, Texas 79701 432-682-8873 432-687-0862 (Fax) x· "..,J~ August 1, 2006 Alaska Oil and Gas Conservation Commission Attn: Mr. John Norman 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 \6~-\O~ RE: Administrative Approval AIO No. 9.007 - MGS Injection Well C24-23 Monitoring Report Dear Mr. Norman: Enclosed is the July 2006 injection rate and wellhead pressure monitoring report for the Middle Ground Shoal C24-23 as required by Administrative Approval AIO No. 9.007. The rate and pressure continue to indicate that there has been no change in the well's mechanical condition. Please contact me with any questions @ 432-620-6742. Sincerely, rJ/AL Jeff Gasch Production Engineer Cc: Paul Figel Scott Griffith Tom Reese Attachments: 1. C24-23 Injection Rate and Pressure Tabular Data 2. C24-23 Injection Rate and Pressure Plot . . C24-23 Rate and Pressure Monitoring Surf Injected Casing Annulus Injection Comments [bbl] [psig] [psig] [psig] 7/1/2006 482 15 3450 3650 7/2/2006 455 16 3450 3650 7/3/2006 471 16 3450 3650 7/4/2006 482 16 3450 3650 7/5/2006 484 16 3450 3650 7/6/2006 455 16 3450 3500 7/7/2006 456 16 3450 3500 7/8/2006 467 16 3450 3500 7/9/2006 449 16 3450 3500 7/10/2006 439 16 3450 3500 7/11/2006 429 17 3450 3500 7/12/2006 423 17 3450 3500 7/13/2006 455 16 3450 3550 7/14/2006 453 16 3450 3550 7/15/2006 462 16 3450 3550 7/16/2006 459 16 3450 3550 7/17/2006 437 16 3450 3550 7/18/2006 437 16 3450 3550 7/19/2006 431 16 3450 3550 7/20/2006 434 16 3450 3550 7/21/2006 447 16 3450 3550 7/22/2006 441 16 3450 3550 7/23/2006 421 16 3450 3550 7/24/2006 421 16 3450 3550 7/25/2006 429 16 3450 3550 7/26/2006 438 16 3450 3550 7/27/2006 462 16 3450 3550 7/28/2006 438 16 3450 3550 7/29/2006 439 16 3450 3550 7/30/2006 427 16 3450 3650 7/31/2006 424 16 3450 3650 XTO Energy - C24-23 Rate and Pressure Monitoring 5000 ·l~. ~;.'.. -~r:~~:b~:~:~~~:~~;u~e.r---'~-~'··-~---·'-~~~·---"-._~-~~_._- ~Surface Casing Pressure _. ---_...~ '-,,- . ------- ._.. ----- ~--_.- --.-.---....- --- 4500 - .--- ---~----~-~----.~----------- ---.-- -~ --------.---~-~.--- --_____..__~___. __~__ _.~__ __ _.____._ _.._ () ... ::J III III ~ 4000 11. I: o :g () ï: oð 3500 III ::J ::J I: I: or:( C) ~ 3000 ~ - - -- -- -- -------- -- -- - ------ - - --~----~_ >< C) III o _····._..__.m._.___......_ __"_' ..__ _._..___ ________ 2500-- --- --~---~------- --- -~ -- ~~ -- ~ ~ -- - ~ ---~- -~--- _u ---~- ---~---- - 100 .'_..U".'._~. II ..~."....".-... . ...... II . ........".'... 2000 0 7/1/2006 7/8/2006 7/15/2006 7/22/2006 7/29/2006 600 500 . GI - III 0:: s:: 0 +:; U GI :E 011 e :I III III GI ~ D.. C) s:: ¡ii III u GI U ~ . :I I/) 300 200 ) -------- Original Message -------- Subject:Re: Status ofC24-23 Injector Date:Fri, 18 Mar 2005 13:17:03 -0600 From:Paul_ Figel@xtoenergy.com To:Thomas Maunder <tom_maunder@admin.state.ak.us> CC:Tom _Reese@xtoalaska.com No. Totally separate well. The C24A-23LN is a West Flank injector. Timing for the temp survey will be in about 2 weeks. Currently, I have the C24-23 SI while we have been fighting the BHP on the new drill offset, C41- 2 3LN. We should be setting the drilling liner in a couple of days. After which, I'll start up injection to get another base line since the well has been SI before we run the temp survey. Paul Thomas Maunder <tom maunder@admi n.stãte.ak.us> 03/18/2005 11: 27 AM Paul_Figel@xtoenergy. com Subj ect Re: Status of C24-23 Injector Paul, I am looking at files, is this C24A- 23LN? Tom Thomas Maunder wrote: If the return is nebulous, then the AA is probably is probably the way to go. That is not a sundry, although the verbiage is roughly in the same form. Just layout the information and include the temperature log. When do you think you might get that done?? I will be out of the office until next Thursday. I have not pulled the file to really > have a look yet. We can talk when I get back. > Tom > > paul_Figel@xtoenergy.com wrote: > » » » » Tom, » Sorry for the delay. Just got from vacation & got hit w/ over 300 » e-mails. » » In regards to the well, the pressure communication has been there for » quite » some time. My hard records date back to Jan 2001 showing press both » on the » tbg & annulus. I hate to speculate the return date to Platform C for the » next program. I was told it might be the Spring of 2006 but Fort » Worth has » a tendency to change their mind. If the reservoir model looks appealing, » they'll move faster & vice versa. There would be no problem running a » temp » survey on the well to verify the inj ection point. I would agree that » filing » a Sundry for an AIO as we did wi th the Al1-13RD2 would be in order. » » Paul » » » » » Thomas » Maunder » <tom_maunder@admi » » n.state.ak.us> To Paul Figel@xtoenergy.com » 11:57 » AM 03/07/2005 cc Subj ect Ioj ector Re: Status of C24-23 (See attached file: C.htm) » > 1 of 1 ) \(~<õ.- \0'\ To cc SCANNED OC1 3 1 2\.\05 ~~ ,"' ~\.r-~J ~ ç \,<-cO~' 10/28/2005 12:34 PM Re: Status of C24-23 Injector ) ) Subject: Re: Status of C24-23 Injector From: Paul_Figel@xtoenergy.com Date: Sun, 06 Mar 2005 18:28:52 -0600 To: Thomas Maunder <tom_maunder@admin.state.alcus> . Tom, At the start of the 2004-05 drilling & workover program in August, I sent you a game plan for the wells we intend to workover & sidetrack. At that time, we intended that the East Flank Injector, C24-23, would be plugged. The well has pressure communication on the tbg annulus (none on the surface csg) and the reservoir dept felt this well was no longer a critical component for East Flank pressure support. However, the last well we completed in December, C22A-26LN, is a West Flank Producer that has a much lower than usual decline compared to all other West Flank new drills over the last 5 years. Tim Smith, my reservoir engineer, is under the suspicion that this injector is actually providing pressure support across the crestal fault into the West Flank, aiding the C22A-26LN. Tim said that he is going to have the West Flank reservoir model from 2001 updated this year with all the production & injection numbers. Based upon those results, his feeling is that we will want to repair the injector & not plug it. The problem is that we should be off platform C by that time & drilling on platform A. I was asked to see if the state will have a problem with us postponing any action on this injector. There was not a Sundry submitted to PM the well. Therefore, XTO would like the AOGCC to allow us to continue to inject & monitor the pressure communication until we have our next Platform C project based upon reservoir modeling. I can't predict when we will move the drilling equipment back from A to C. Please advise what would be acceptable for the state. Thanks, Paul By the way, I will be off on Spring Break until the 14th. Paul Figel Engineering Manager XTO Energy Inc. Midland, TX Office: 432-620-6743 Mobil: 432-553-5217 Fax: 432-687-0862 ~ANNEr) OCT 3 12.005 -----Thomas Maunder <tom__maunder@admin.state.ak.us> wrote: ----- To: Paul_Figel@xtoenergy.com From: Thomas Maunder <tom_maunder@admin.state.ak.us> Date: 03/04/2005 03:57PM Subject: Re: Status of C24-23 Injector Paul, I have to ask you to refresh my memory on this well. I can't find the notes I took when we talked. Sorry about that. As I remember, your proposal was not unreasonable. But I don't remember the specifics. Tom paul_Figel@xtoenergy.com wrote: lof2 3/17/2005 8:57 AM Re: Status of C24-23 Injector ) ) > > >Tom, >Did you have a chance to review the injector C24-23 that I called about? We >were wanting to postpone the P&A to evaluate this well in the reservoir >model for the West Flank & possibly fix the communication to give flood >support for the last new drill C22A-26LN. We would take action on the next >drill program on Platform C. > >Thanks for your help, >Paul > >Paul Figel >Engineering Manager >XTO Energy Inc. >Midland, TX >Office: 432-620-6743 >Mobil: 432-553-5217 >Fax: 432-687-0862 > > > > 2of2 3/17/2005 8:57 AM November-2002 C23-23 ACT DATE & NOTES I~ INJ ANNU 01-Nov-2002 02-Nov-2002 03-Nov-2002 ' 04-Nov-2002 05-Nov-2002 06-Nov-2002 07-Nov-2002 08-Nov-2002 09-Nov-2002 10-Nov-2002 11-Nov-2002 12-Nov-2002 13-Nov-2002 14-Nov-2002 15-Nov-2002 16-Nov-2002 1 ?-Nov-2002 18-Nov-2002 19-Nov-2002 20-Nov-2002 21 oNov-2002 22-Nov-2002 23-Nov-2002 24-Nov-2002 25-Nov-2002 26-Nov-2002 27~Nov-2002 28-Nov-2002 29-Nov-2002 30-Nov-2002 1854 3450 1848 3450 1764 3450 1759 3450 1769 3450 1814 3450 1823 3450 1851 3450 1861 3450 1815 3450 1818 3450 1793 345O 1750 3450 1758 3450 1763 345O 1751 3450 1707 3450 1716 3450 1722 3450 1722 3450 1732 3450 1704 3450 1706 3450 1729 3475 1709 3475 1703 3475 1700 3475 1704 3450 1675 3450 1686 345O WATER INJECTION REPORT PLATFORM C ACT-- IN3 INJ ANNU ACT l~J INJ ANNU 398 3475 355C 399 3500 355C 389 3500 350( 388 3450 350( 386 3450 350( 393 3400 345( 396 3550 350( 402 3550 350( 402 3550 350( 396 3500 350( 394 3500 350( 397 3500 345I 398 3500 345( 66 1350 1351 0 1100 110( 0 1050 105( 0 1050 105( 0 I000 1~0( 0 1000 1001 0 1000 I001 440 3500 34751 421 3500 3475 418 3500 3450 421 3500 3475 397 3500 3475 413 3500 3475 411 3500 3475 409 3450 3450 403 3450 3450 404 3450 3450 C23-26 ACT ! ACT INJ INJ A~NU i l~J ]~/J A.NNU 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 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 0 0 0 0 0 0 C41-26 ACT EqJ INJ ANN[ C44-14RD j A~' INJ l]qJ ANNU 0 50 511 0 50 511 0 50 511 0 50 511 o 5o 51~ 0 50 510 0 50 560 0 50 560 0 50 560 0 50 560 0 50 560 0 50 560 0 50 560 0 50 560 0 50 560 0 50 560 0 50 560 0 50 56~ 0 50 56~ 0 50 56~ 0 50 511] 0 50 511] 0 50 51(] 0 50 51(] 0 50 5t(] 0 50 51(] 0 50 510 0 70 56C 0 70 56C 0 70 56(: 587 3450 573 3450 496 3400 498 3400 · 502 3400 533 3400 599 3450 634 3450 597 3450 605 3450 662 3450 667 3450 620 3450 670 3450 566 3450 494 3450 555 3450 583 3450 583 3450 604 3450 634 3500 631 3500 697 3450 682 3500 665 3500 683 3450 673 3475 687 3450 714 3450 715 3450 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 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 0 0 0 0 0 0 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 575 0 0 550 0 0 550 0 0 550 0 0 55(] 0 0 55(] 0 0 55(] 0 0 55(] 0 0 55(] 0 0 55(] 0 0 55r~ 0 0 551~ 0 0 55C 0 0 55C 0 0 55C 0 0 55C 0 0 55C 0 0 55C 0 0 55C 0 0 55C 0 0 57': 0 0 55C 0 0 55C 0 0 50( 0 0 55( C24A-14 ACT INJ INJ ANNU 369 4450 37O 4450 373 4450 442 4550 421 4550 407 4525 416 4550 412 4550 412 4550 405 4560 380 4560 389 4550 407 4550 403 4500 395 4500 400 4500 4O4 45OO 4(72 4450 387 4450 396 4450 399 4450 394 4450 385 4450 401 4500 381 4500 388 4500 369 4500 357 4450 362 4450 387 4450 TOTAL 52,706 0 9,341 18.409 0 0 0 11,813 MAXIMUM 3,475 70 56~ 3.550 3.550 3,500 0 0 0 57~. 4,560 AVERAGE 1.757 3,453 0 52 538 311 2,928 2,922 6t4 3,451 0 0 0 0 0 0 55C 394 4,497 # DAYS 30 0 24 30 0 0 0 30 12/12/2002 241-23 shut in due *-o annular communication probk~m. WATER INJECTION REPORT PLATFORM C October-2002 C23-23 C41-23 C24-23 C34-23 C23-26 C41 ~26 C44-14RD C24A- 14 DATE & NOTES 01-0ct-2002 02-Oct-2002 03-Oct-2002 04-Oct-2002 05-0ct-2002 06-Oct-2002 07-Oct-2002 08-Oct-2002 10-Oct-2002 11-Oct-2002 12-Oct-2002 13-Oct-2002 14-Oct-2002 15-Oct-2002 16-Oct-2002 17-Oct-2002 18-Oet-2002 19-Oct-2002 20-Oct-2002 21-Oct-2002 22-Oct-2002 23-Oct-2002 24-Oct-2002 25-Oct-2002 26-Oct-2002 27-Oct-2002 28-Oct-2002 29-Oct-2002 30-Oct-2002 31 -Oct-2002 TOTAL MAXIMUM AVERAGE # DAYS 11/12/2002 A~ NJ ANNU ACT INJ INJ AN/~ ACT INJ INJ ANNU ACT INJ INJ ANNU ACT INJ liqJ ANNI ACT INJ INJ ANNU ACT INJ 1NJ ANNU 1808 3450 1809 3475 1808 3475 1815 3475 1809 3475 1795 3475 1813 3475 1824 3475 1803 3475 1756 3475 1755 3475 1776 3475 1771 3450 1830 3450 1775 3450 1807 3450 1820 3450 1827 3450 1836 3450 1808 3450 1827 3450 1799 3450 1832 3450 1802 3460 1812 3460 1708 3460 1874 3450 1784 3475 1810 3460 1846 3460 1851 3450 55,990 3,475 1,806 3,461 31 0 50 510 0 50 560 0 50 560 0 50 560 0 50 560 0 50 560 0 50 560 0 50 560 O 50 560 0 50 560 0 50 560 0 50 560 0 50 560 0 50 560 0 50 560 0 50 560 0 50 56(3 0 50 560 0 50 560 0 50 560 0 50 560 0 50 560 O 50 56~ 0 80 520 0 80 510 O 80 510 0 50 510 0 50 515 0 50 510 O 50 51{3 0 50 510 0 80 560 0 53 546 0 411 3500 345£ 408 3525 3475 405 3525 3475 404 3525 3475 395 3525 3475 404 3525 3~75 405 3525 3475 405 3525 3475 400 3525 3475 398 3525 3475 399 3525 347/ 403 3525 347/ 400 3500 350( 410 3500 350( 394 3500 350( 401 3500 350( 402 3500 350( 402 3500 350( 406 3500 350( 400 3500 350( 405 3500 350( 400 3500 350( 405 3500 350( 402 3500 347/ 407 3500 347/ 389 3500 347.~ 410 3500 350( 389 3500 345C 390 3500 347/ 397 3500 347/ 397 3500 350( 12,443 3,525 3,50C 401 3,509 3,484 31 669 3500 8(] 637 3500 6~ 617 35OO 6~ 688 3500 6~ 650 3500 6C 628 3500 6~ 687 3500 6~ 631 3500 6C 629 3500 6C 548 3500 6~ 546 3500 6~ 579 3500 6~ 640 3450 654 3450 574 3450 558 3450 565 3450 491 3450 522 3450 556 3450 584 3450 572 3450 546 3450 551 3500 595 3500 543 3450 628 3475 699 3450 579 3500 615 3475 630 3450 18,6ll 3,500 8~ 600 3,476 24 31 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 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 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 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 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 0 550 0 0 550 0 0 550 0 0 55(3 0 0 550 0 0 575 0 0 55~ 0 0 55(3 0 0 55(] 0 0 55(] 0 0 55(] 0 0 55(3 0 0 55(3 0 0 55(] 0 0 55(] 0 0 55(] 0 0 55(] 0 0 55(] 0 0 55(] 0 0 55(] 0 0 55(] 0 0 55(] 0 0 55(] 0 0 55(] 0 0 55(] 0 0 575 0 0 55(] 0 0 55(] 0 0 50~ 0 0 55(] 0 0 50~ 0 0 575 0 0 548 0 ACT INJ I~$ ANNE 410 4500 192 3500 337 4500 428 4500 413 4500 397 4500 417 4500 402 4500 403 4500 425 4500 413 4500 381 4500 379 4500 405 4500 407 4575 387 4575 412 4550 412 4550 419 4550 415 4550 412 4550 410 4550 437 4550 4O9 46OO 418 4600 388 45OO 405 4500 373 4500 382 450O 393 4500 394 4450 12,275 4,600 396 4,489 31 C41-23 shut in due to annular communication problem. 2.003 WATER INJECTION REPORT PLATFORM C September-2002 C23 -23 C41-23 C24-23 C34-23 C23-26 C41-26 C44-14RD C24A-23 C24A- 14 ACT ACT ACT ACT ACT ACT ACT ACT ACT DATE & NOTES ]NJ INJ ANNU INJ INJ ANNU INJ INJ ANNU INJ INS ANN[ l.NJ INJ ANNU INJ INJ ANNU ]NJ INJ ANNU INJ INJ ANNL INJ INJ ANNL OI-Sep-2002 02-Sep-2002 03-Sep-2002 04-8ep-2002 05-8ep-2002 06-Sep-2002 07-Sep-2002 08-Sep-2002 09-$ep-2002 10-SeI~2002 11-$ep-2002 12-Sep-2002 13-Sep-2002 14-Sep-2002 15-5ep-2002 16-Sep-2002 [ 7-S¢p-2002 18-Sep-2002 19-Sep-2002 20-$ep-2002 21-Sep-2002 22-Sep-2002 23-Sep-2002 24-Sep-2002 25-Sep-2002 26-Sep-2002 27-Sep-2002 25-Sep-2002 29-8ep-2002 30-Sep-2002 TOTAL MAXIMUM AVERAGE # DAYS 10/14/2002 1844 3475 1859 3475 35 1861 3500 1865 3500 31 1863 3500 1864 3500 3C 1860 3500 1861 3500 25 1868 3500 1841 3500 2/ 1853 3500 2/ 1841 3500 2/ 1836 3500 22 1850 3500 2/ 1868 3500 2/ 1870 3500 2~ 1845 3500 2/ 1864 3500 2/ 1693 3500 2/ 1768 3450 2/ 1777 3450 22 1767 3450 PA 1765 3450 2-` 1778 3450 2-` 1778 3450 1798 3450 1804 3450 1827 3475 1674 3450 1429 3450 54,271 3,500 35i 1,809 3,481 21 30 : 0 50 511 0 50 50( 0 50 511 0 50 511 0 50 5 Il 0 50 511 0 50 51l 0 50 51( 0 50 51( 0 50 511 0 50 51( 0 40 55; 0 40 55.' 0 40 56/ 0 50 56/ 0 80 561 0 60 56/ 0 50 56/ 0 50 56/ 0 50 56/ 0 50 56~ 0 50 5~0 0 50 560 0 50 560 0 50 560 0 50 560 0 50 560 0 50 555 0 50 550 0 50 510 0 80 560 0 50 539 0 415 3550 350( 417 3550 350( 417 3550 350( 415 3550 350( 416 3550 350( 414 3550 350( 415 3500 350( 412 3500 350( 413 3500 350( 410 3500 350( 412 3500 350( 408 3500 350( 407 3500 350( 408 3500 350( 406 3500 3525 405 3500 350( 399 3500 3525 400 3500 350( 372 3500 350( 388 3450 345( 131 3450 345( 0 1100 1101 0 1050 105{ 0 1000 1001 173 3500 350( 419 3500 346( 413 3500 346( 417 3550 347~ 393 3500 347~ 328 3550 347~ 10,423 3,550 3,525 347 3,265 3,24~ 27 833 3550 125 880 3550 125 917 3550 13¢ 909 3550 125 862 3550 125 790 3550 125 783 3500 11£ 773 3500 755 3500 II( 766 3500 111 774 3500 111 746 3500 105 787 3450 105 769 3500 107 826 3500 102 794 3500 111 688 3500 111 666 3500 11( 626 3500 105 678 3450 102 601 3450 102 697 3450 760 3450 10: 801 3450 101 597 3450 ( 605 3450 2/ 632 3450 660 3475 11( 621 3500 600 3500 22,196 3,550 13( 740 3,494 101 30 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 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 0 0 0 0 0 0 0 730 60( 0 730 60( 0 730 60( 0 730 60( 0 730 60( 0 730 60( 0 730 60( 0 730 60( 0 730 60( 0 730 60( 0 730 60( 0 730 57; 0 730 57; 0 735 57; 0 735 57~ 0 735 57; 0 735 57; 0 735 57; 0 735 57; 0 735 57-` 0 735 57~ 0 735 57~ 0 735 57~ 0 735 57~ 0 735 57-` 0 735 600 0 735 600 0 735 600 0 730 600 0 730 600 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 575 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 55~ 0 0 55~3 0 0 55~3 0 0 55~ 0 0 55~ 0 0 55C 0 0 5~ 0 0 55C 0 0 55C 0 0 575 0 0 55~ 0 0 55£ 0 0 50~ 0 0 55C 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 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 0 0 0 0 0 0 40O 4450 412 4500 417 4500 430 4525 424 4525 432 4525 415 4500 402 4500 391 4500 402 4500 394 45OO 389 445O 396 4450 391 4450 396 4500 398 4500 408 45OO 401 4500 368 4500 391 4500 391 4500 393 4500 394 4500 394 4500 380 4450 360 4450 360 4450 389 45OO 416 4550 342 4525 C41-23 shut in due to annular communication problem. C24A-23 shut in for field study and evaluation per Doug Marshal]. 0 0 0 0 11,876 0 735 600 0 575 0 4,550 0 0 0 733 588 0 0 55£ 0 0 396 4,493 0 0 0 0 30 BC;ANNED i 0 2003 i WATER INJECTION REPORT PLATFORM C I une-2002 C28-2~3 C41-23 (224-23 C34-23 C23-26 C41-26 C44-14RD C24A-23 C24A- 14 ACT l~J ACT ACT ACT ACT ACT ACT ACT ACT DATE & NOTES INJ ANNUINJ IHJ ANNU INJ INJ ANNUIN.I INS ANNU IHS INI AHNU IHJ INJ ANNUIHI INJ ANNU INI IHS ANNI INI INS ANN: 01 oJun-2002 1770 35~)0 0 0 0 616 371 3450 3450 0 0 0 0 fl 0 ~ 251 1,080 1,800 550 0 0 0 191 3500 02-Jun-2002 1776 35~0 00 0 615; 373 8450 3450 0 0 0 0 fl 0 440 250 32~ 1,800 550 0 0 0 175 3500 03-Jun-2002 1760 35~)0 0 0 0 615 369 3450 3450 0 0 0 0 fl 0 440 251 220 1,800 550 0 0 0 203 3500 04-Jun-2002 1764 34}0 0 0 0 615 373 3425 3426 0 0 0 0 fl 0 440 2S 0 0 550, 0 0 0 203 3500 05-Iun-2002 1376 3450 0 0 0 6151 291 3425 3425 0 0 0 0 0 0 440 2:5(0 0 550: 0 0 0 1551 3500 06o$Un-2002 1198 34~0 0 0 0 611 242 33:50 3400 0 ! 0 0 0 fl 0 :570 40( 0 0 575; 0 0 0 1411 3500 07-1un-2002 970 34~10 0 0 0 61:5[ 219 3350 3400 0 0 0 0 (] 0 :5?0 40( 0 0 550[ 0 0 0 118i 3500 08-1un-2002 612 3480 0 0 0 61:5[ 398 3400 8450 0 : 0 0 0 (] 0 :590 40( 272 1,900 $8( 0 0 0 22:51 3500 09-Iun-2002 1416 3450 0 0 0 611 291 3400 34:50 0 ; 0 0 0 0 0 600 40( 377 1,800 55( 0 0 0 1:52! 3:500 10-Jun-2002 1950 3430 0 0 0 611 394 342:5 347:5 229 3500 ( 0 0 0 0 600 40( 0 0 55( 0 0 0 203 3:500 11 -Jun-2002 1876 34:50 0 0 0 611 386 34:50 3:500 410 3500 C 0 0 0 0 610 4:5( 0 0 6:5( 0 0 0 222! 3:500 12dun-2002 1849 3:500 0 0 0 611 387 34:50 3500370 8500 £ 0 0 0 0 620 4:5(3'72 1,800 55( 0 0 0 20:5! 3:500 13dun-2002 1846 3500 0 0 0 611 382 34:50 8:500 430 3:500 C 0 0 0 0 620 4:5( 686 1,800 :5:5( 0 0 ~ 194! 8500 1 4-Jun-2002 18:58 3:500 00 0 611 382 34:50 3:50( 484 3:500 C 0 0 0 0 620 4:5(432 1,800 :5:5(0 0 0 432: 4100 15-1un-2002 1864 3500 0 0 0 611 384 3450 3:50( 619 3:500 ¢ 0 0 0 0 620 4:5( 0 0 :5:5( 0 0 403 4:500 16-Jun-2002 1865 3500 0 0 0 611 384 3450 3:50(634 3500 13 0 0 0 0 620 4:5(393 1,800 5:5(30 0 4:57 4:500 13 17-Jun-2002 1877 3500 0 0 0 61( 383 3450 350( 636 3500 {~ 0 0 0 0 620 45( 0 0 55C 0 0 438 4500 C 18-Jun-2002 1895 3500 0 0 0 61( 384 3450 350( 625 3500 fl 0 0 0 0 620 45£ 386 1,850 55(3 0 0 341 4450 19-Jun°2002 1864 3500 0 0 0 61( 380 3450 350( 661 3500 0 0 0 0 0 620 45£ 312 2.100 55(3 0 0 352 4450 20-Jun-2002 1885 3500 0 0 0 61.' 381 3475 350( 693 3500 (3 0 0 0 0 660 50C 0 0 55(3 0 0 347 4450 21-Jun-2002 1824 3500 0 0 0 61.~ 374 3475 350( 579 3500 0 0 0 0 0 665 50C 340 1.900 55fl 0 0 317 4500 C 22-$un-2002 1848 35~30 0 0 0 61.~390 3450 350( 470 3500 0 0 0 0 0 720 50C 0 0 55(] 0 0 301 4400 23-Jun-2002 1874 3500 0 0 60 615 386 3500 350( 491 3500 0 0 0 0 0 670 50(3 0 0 550 0 0 314 4400 0 24-Jun-2002 1757 34b0 0 60 62£ 370 3400 345( 388 3425 0 0 0 0 675 50~ 354 1,900 550 0 0 342 4500 25-Jun-2002 1843 3450 0 60 62£379 3450 350( 485 3500 0 0 0 0 725 50(]0 0 550 0 0 346 4500 26-$un-2002 1867 3500 0 60 615 371 3450 350( 568 3500 0 0 0 0 680 50~ 332 1,900 575 0 0 (3 358 4500 27-Jun-2002 1923 34~50 0 60 615 373 3500 350( 559 3500 0 0 0 0 680 500 360 2,000 550 0 0 £ 336 4500 0 28-Jun-2002 1922 34i0 0 60 615365 3500 350( 557 3500 0 0 0 0 680 50~ 0 0 550 0 0 (3 0 2800 0 29-1un-2002 1916 34~50 0 60 615362 3500 350C 524 3500 0 0 0 0 680 50(]0 0 500 0 0 (319 2800 0 30-$un-2002 1903 34~0 0 60 615 359 3500 350C 547 3500 0 0 0 0 680 500 353 2,000 550 0 0 (3 526 4400 0 TOTAL 51.948 [ 0 10,883 10.959 0 0 6.594 0 8,016 MAXIMUM 3.5~X) C 60 620 3.500 3,500 3,500 0 0 (3 725 500 2,100 575 0 0 4,500 AVERAGE 1,732 3,412 ¢ 0 16 614 363 3,446 3,478 365 2,448 0 0 0 C 0 607 427 220 998 550 0 0 0 267 3,925 01 # DAYS 30 0 30 20 0 0 16 0 07/11/2002 I 29 I C41-23 shut in due to annular communication problem. C24A-23 shut in for field study and evaluation p~r Doug M~xshall. I GANNED 1 0 2003 WATER INJECTION REPORT PLATFORM C August-2002 C23-23 C41-23 C24-23 C34-23 C23 -26 C41-26 C44-14RD C24A-23 C24A- 14 ACT ACT ACT ACT ACT ACT ACT ACT ACT DATE & NOTES ~qJ INJ ANNU ]NJ INJ ANNU INJ [NJ ANNU ]NJ INJ ANNU INJ INJ ANNU INJ I~J ANNU INJ INJ ANNU INI INJ ANNU IN~ 1NJ ANN~ 01-Aug-2002 965 2500 620 80 55( 198 1250 1250 481 1950 1(0 0 0 0 720 550 454 2,050 550 0 0 0 470 4450 02-Aug-2002 1985 3500 22 0 70 55i 408 3500 3500 860 3500 I( 0 0 0 0 720 575 409 2,200 550 0 0 0 503 4600 03-Aug-2002 1919 3500 30 0 70 55i 405 3500 3525 959 3500 11 0 0 0 0 725 575 0 0 550 0 0 0 485 4600 04-Aug-2002 1897 3500 30 0 60 55{ 404 3500 3550 927 3500 11 0 0 (l 0 725 575 390 1,950 550 0 0 0 463 4650 05-Aug-2002 1865 3500 32 0 60 55( 400 3500 3500 855 3500 11 0 0 0 0 725 575 0 0 550 0 0 0 471 4700 06-Aug-2002 1850 3500 35 0 60 55( 298 3500 3550 865 3500 11 0 0 0 0 725 575 300 1,800 575 0 0 0 449 4700 07-Aug-2002 1880 3500 28 0 60 55( 0 0 1150 862 3500 1( 0 0 0 0 725 575 0 0 550 0 O 0 432 4650 0B-Aug-2002 1871 3500 28 0 60 55{ 0 0 1150 840 3500 1( 0 0 0 0 725 575 0 0 550 0 0 O. 350 4650 09-Aug-2002 1867 3500 28 0 60 55{ 0 0 1150 809 3500 Ii 0 0 0 0 725 575 0 0 550 0 0 0 407 4650 10-Aug-2002 1863 3500 28 0 60 55( 0 0 1150 670 3500 11 0 0 0 0 725 575 0 0 550! 0 0 0; 406 4450 11 -Aug-2002 1826 3500 28 0 60 55{ 0 0 1150 592 3500 11 0 0 0 0 725 575 0 0 550 0 0 0 392 4450 12-Aug-2002 1852 3500 28 0 60 55( 0 0 1150 573 3500 11 0 0 0 0 ' 725 575 0 0 550i 0 0 0 410 4450 13-Aug-2002 1867 3500 28 0 60 55{ 0 0 1150 614 3500 1( 0 0 0 0 725 575 0 0 550i 0 0 13, 411 4450 14-Aug-2002 1852 3500 28 0 60 55{ 0 0 1150 660 3500 Ii 0 0 0 0 725 575 0 0 550 0 0 /3'418 4450 15-Aug-2002 1870 3500 13 0 80 56( 0 0 975 660 3500 11 0 0 0 0 725 575 0 0 550~ 0 0 0 420 4500 16-Aug-2002 1854 3475 12 0 60 555 0 0 950 640 3500 1( 0 0 0 0 725 575 0 0 550] 0 0 ff 402 4500 17-Aug-2002 1812 3500 15 0 80 56( 32 3500 950 622 3500 1( 0 0 0 0 725 575 0 0 5501 0 0 ~ 411 4500 lg-Aug-2002 1808 3475 40 0 70 56( 303 3500 3125 870 3450 1( 0 0 0 0 725 575 0 0 55( 0 0 ~ 413 4500 19-Aug-2002 1763 3500 45 0 50 55-`326 3500 3150793 3450 11 0 0 0 0 725 575 0 0 55( 0 0 I~ 380 4500 20-Aug-2002 1786 3450 40 O 50 55-`390 3500 3500754 3450 II 0 0 0 0 725 575 0 0 55( 0 0~ 389 4400 2 I-Aug-2002 1810 3450 37 0 50 55.' 391 3500 3500 804 3400 11 0 0 0 0 725 575 0 0 55( 0 0 I~ 384 4400 22-Aug-2002 1817 3475 36 0 50 55-` 390 3500 3500 875 3475 1( 0 0 0 0 725 575 0 0 55i 0 01~ 390 4400 23-Aug-2002 1811 3475 36 0 50 55-` 340 3500 3500 835 3475 1( 0 0 0 0 725 575 0 0 55( 0 0 384 4400 24-Aug-2002 1764 3475 36 0 50 55.' 0 0 3500 593 3475 1( 0 0 0 0 725 575 0 0 55( 0 0 391 4400 25-Aug-2002 1782 3475 36 0 50 55-`0 0 3500 625 3475 11 0 0 0 0 725 575 0 0 55( 0 0 401 4400 26-Aug-2002 1785 3450 0 0 50 55-`198 3500 1000682 3450 11 0 0 0 0 725 575 0 0 575 0 0 421 4400 27-Aug-2002 1787 3450 0 0 50 55.' 265 3475 3475 864 3450 11 0 0 0 0 725 575 0 0 55£ 0 0 407 4400 28-Aug-2002 1734 3475 0 0 50 55.' 145 3500 3350 852 3450 11 0 0 0 0 725 575 0 0 56( 0 0 372 4500 29-Aug-2002 1528 3475 0 0 50 555 363 3500 3350724 3450 II 0 0 0 0 725 575 0 0 50i 0 0 380 4500 30-Aug-2002 1793 3475 0 0 50 505 417 3550 3500 770 3550 11 0 0 0 0 730 575 0 0 55£ 0 0 385 4400 31 -Aug,-2002 1830 3475 30 0 50 511 417 3550 3500 848 3550 11 0 0 0 0 730 600 0 0 55£ 0 0 399 4450 TOTAL 55,693 0 6,090 23,378 0 0 1,553 0 12,796 MAXIMUM 3,500 62 80 56£ 3,550 3,550 3,550 1£ 0 0 730 600 2,200 575 0 4,700 5 AVERAGE 1,797 3,453 26 0 59 55£ 196 2,075 2,465 754 3,435 1£ 0 0 0 0 725 575 50 258 55£ 0 0 413 4,498 2 //DAYS 31 0 19 31 0 0 4 0 31 09/16/2-002 C41-23 shut in due to annular communication problem. C24A-23 shut in for field study and evaluation per Doug Marshall. SGANNED 1 t) 2003 February-200 I o I -Feb-200 ! 02-Feb-2001 03-Feb-2001 04-Feb-200 I 05-Feb-200 I 06-Feb-2001 07-Feb-200 I 08-Feb-200 ! 09-Feb-200 ! 10-Feb-2001 I 1-Feb-2001 ! 2-Feb-2001 13-Feb-200 I 14-Feb-200 i 15-Feb-2001 16-Feb-2001 i 7-Feb-2001 18-Feb-2001 19-Feb-2001 20-Feb-2001 21 -Feb-200 I 22-Feb-2001 23-Feb-2001 24-Feb-2001 25-Feb-2001 26-Feb-2001 27-Feb-200 I 28-Feb-2001 TOTAL AVERAGE # DAYS ACT C23-23 ] ACT ANNU INJ [NJ INJ 1762 3250 325( 1632 3250 325( 1702 3250 325( 1696 3250 325( 1693 3250 325( 1710 3200 320( 1694 3200 320( 1708 3200 320( 1667 3200 320( 1653 3200 320( 1680 3200 3200 WATER INJECTION REPORT PLATFORM C CAI~23[Nj ANNUl ACT C24.23 INJ INJ ANNU 0 500 520 0 500 520 0 500 52C 0 500 520 0 500 52¢ 0 500 52C 0 500 52C 0 500 52( 0 500 52C 0 500 52C 0 500 52( 386 3500 350( 379 3500 350( 393 3500 350( 389 3500 350( 386 3500 350( 386 3450 345( 384 3450 345( 385 3450 345( 382 3450 345( 375 3450 3450 379 3450 3450 C34~23 ACT [NJ [NJ A.~ 1742 3200 320( 1665 3200 320( 1741 3200 320( 1730 3200 320( 1727 3200 3200 .1733 3200 3200 1727 3200 3200 1745 3200 3200 1728 3200 3200 1711 3200 3200 · 1729 3200 3200 1674 3200 3200 1667 3200 3200 1674 3200 3200 1647 3250 3200 1652 3250 3200 1649 3250 320~ 1648 3250 3200 1654 3250 3200 1644 3250 320~ 1445 3250 320~ 0 2200 220~ 0 2200 220( 0 1900 1825 0 1850 177~ 0 1750 175( 0 1750 165( 0 1750 165{ 34,951 3,250 3,250 1~48 2,900 2,875! 21 0 500 52( 0 500 52( 0 500 52( 0 500 525 0 500 525 0 500 525 0 500 525 0 500 525 0 500 525 0 500 525 0 500 525 0 500 525 0 500 525 0 500 525 0 500 525 0 500 525 0 500 525 382 3450 3450 380 3450 3450 381 3450 3450 372 3450 3425 373 3450 3425 368 3500 3450 368 3500 3450 367 3500 3450 366 3500 3450 333 3500 3450 237 1500 1650 77 1500 165C 425 3450 345£ 406 3450 345( 406 3450 345( 425 3500 350( 423 3500 350( 0 500 525 0 500 523 0 10,313 3,500 3,50~ 368 3,332 3,332 28 1739 3200 3200 1728 3200 3200 1737 3200 3200 1707 3200 3175 1714 3200 3175 1706 3500 3200 1704 3500 320~ 1708 3500 320~ 1696 3500 3175 1533 3500 3175 887 1800 162~ 291 1800 162~ 1949 3050 330( 1863 3300 330( 1873 3300 330( 2003 3400 340( 2000 3400 340( 46,816 3,500 3,400 1,672 3,170 3,109 28 03112/2001 C41-23 shut in due to annular communication problem. C34-23 has developed an annular communication problem. AOGCC notified on 12/12/99. Vethal approval to continue to inject received from Mr. Wondzell on 12/14/99. C23-23 shut in for upcoming drilling operation at the end of March. All injectors have reduced inected barrels on 2/22 & 2/23 to change nccumulator relief valve. C23-26 C41-26 C44-14RD C24A-23 ACT ACT ACT ACT [NJ [NJ ANNU [NJ [NJ ANNU [NJ [NJ ANNU [NJ INJ ANNU o o o o o o 0 0 o o 0 0 o o o 0 o o o 0 0 o o o 0 o o 0 0 0 0 o o o 0 o o o 0 o o o o 0 o o 0 o o o 0 o o o 0 0 0 o 0 o o 0 800 650 0 800 650 0 g00 650 0 800 650 0 800 650 0 800 650 0 800 650 0 800 650 o 800 650 0 800 650 0 800 650 0 800 65~ 0 800 65C 0 0 550 0 0 550 0 0 ' 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 248 4400 253 4475 277 4500 272 4500 259 4500 266 4525 262 4525 252 4525 250 4500 246 4500 243 4500 258 4500 256 4500 C24A- 14 [NJ [NJ ANNU 0 800 65C 0 800 65C 0 800 65( 0 800 65( 0 800 65( 0 800 65( 0 180 10( 0 300 10.' 0 300 I0.~ 0 300 10: 0 300 105 0 300 105 0 3OO 105 o 300 105 0 300 105 0 0 800 650 0 0 635 475 0 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 O' 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 55O 0 0 550 0 0 550 0 0 550 247 4500 246 4450 253 4450 251 4450 248 4450 247 4500 257 4500 260 4500 162 4500 19 4500 263 4350 283 4400 286 4550 286 4500 268 4500 o o 550 o 0 550 356 4475 357 4525 399 4575 392 4575 387 4575 382 4575 370 4575 369 4575 366 4550 369 4550 364 4550 359 4550 355 4550 6,918 4,550 247 4,484 28 362 4550 35~ 4500 359 4500 356 4500 360 4500 362 4500 365 4500 368 4500 225 3000 32 3000 423 4350 426 4350 421 4550 401 4550 396 4550 10,040 4,575 0 359 4,414 0 28 RECEIVED MAR 1 3 2001 Alaska Oil & Bas Cons. Commission Anchorage January-2001 0 l-Jan-2001 02-Jan-2001 03-,lan-2001 04-,lan-2001 05-Jan-2001 06-Jan-2001 07-Jan-2001 08-$an-2001 09-.lan-2001 10-Jan-2001 1 l-Jan-2001 12-Jan-2001 13-,lan-2001 14-,lan-200 ! 15-Jan-2001 16-,lan-2001 17-,lan-2001 18-,lan-2001 19-Jan-2001 20-,lan-2001 2 I-,lan-2001 22-,lan-2001 23-,lan-2001 24-Jan-2001 25-,lan-2001 26-Jan-2001 27-Jan-2001 28-.lan-200 1 29-Jan-2001 30-Jan-2001 3 I-,lan-2001 TOTAL MAXIMUM AVERAGE # DAYS 02/12/2001 C23-23 ACT IN,l INJ ANNU C41-23 WATER IN,IECTION REPORT PLATFORM C ACT INJ INJ ANNU C24-23 C34-23 C23-26 C41-26 ACT ACT IN,l INJ ANlqU XNJ INJ Ab,'-NU 0 0 0 780 625 0 0 0 780 625 0 0 ~ 0 780 625 0 0 0 0 780 650 0 0 0 0 780 625 0 0 0 0 780 625 0 0 0 0 780 625 0 0 0 0 785 650 0 0 0 0 785 650 0 0 0 0 785 650 0 0 0 0 785 65C 0 0 0 785 65C 0 0 0 785 65~ 0 785 65C 0 785 65¢ 0 785 65C 0 790 65C 0 650 79f 0 790 65{ 0 790 65C 0 790 65C 0 79O 65C 0 79O 65( 0 790 65( 0 790 65( 0 790 65( 0 790 65( 0 790 65( 0 790 65( 0 790 65( 0 790 65( C44-14R.D ACT INJ INJ ' ANNU 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 55O 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 C24A-23 C ACT ~NL~J A INJ INJ ANN! 141 3400 132 3400 135 3400 - .129 3500 110 120 3500 105 144 3350 0 252 4100 1.~0 294 4250 271 4350 272 4350 269 4350 260 4350 0 264. 4450 '0 412 4400 1732 3250 3250 1749 3250 3250 1775 3250 3250 1822 3300 3250 1748 3300 3250 1726 3250 3250 1758 3300 3250 1792 3250 3250 1783 3250 3250 1773 3300 3250 1750 3300 325¢ 1748 3300 325C 1760 3250 325~ 1752 3250 325{ 1760 3250 325{ 1773 3250 325( 1730 3250 322.' 1737 3225 322.~ 1653 3250 32251 1781 3250 3250 1562 3250 3250 1709 3250 3250 1730 3250 3250 1732 3250 3250 1738 3250 3250 1748 3250 3250 1707 3250 3250 1758 3250 3250 1741 3250 3250 1752 3250 3250 1752 3250 3250 54,031 3,300 3,250 1,743 3,259 3,248 31 0 500 52¢ 0 500 52¢ 0 500 5~ 0 500 5~ 0 500 52( 0 500 52£ 0 500 5~ 0 500 5~ 0 500 525 0 500 5~ 0 500 5~ 0 500 5~ 0 500 525 0 500 525 0 500 525 0 500 525 0 500 520 0 500 520 0 500 525 0 500 525 0 500 525 0 500 525 0 500 525 0 500 525 0 500 525 0 500 525 0 500 525 0 500 525 0 500 525 0 500 525 0 500 525 0 500 525 0 500 524 0 ACT INJ INJ ANNU 371 3400 3400 370 3400 3400 373 3400 3400 389 3500 3500 377 3500 3500 371 3400 3400 380 3450 3450 386 3450 3450 384 3450 3450 387 3450 3450 379 3450 3450 376 3450 3450 378 3450 345(] 380 3450 345{] 382 3450 345(] 382 3450 3450 37 ! 3425 3425 371 3400 345£ 371 3450 345£ 393 3450 345( 355 3450 345{ 375 3450 345{ 378 3450 345{ 377 3450 345{ 376 3450 345{ 377 3450 345{ 376 3450 345( 390 3450 345( 382 3450 345{ 387 3450 345( 381 3450 345( 11,725 3.500 3.50( 378 3.444 3,446 31 ACT INJ INJ ANNU 1618 2950 3150 1616 2950 3150 1630 2950 3150 1678 3200 320~ 1609 3ooo 320( 1623 2950 3150 1634 2950 320( 1654 3200 320( 1642 3200 320( 1640 2950 320(3 1621 2950 320( 1610 2950 320( 1621 3200 320( 1616 3200 320( 1627 3200 320( 1631 3200 320( 1589 3200 320( 1593 3200 320( 1529 · 3200 320( 1657 3200 320( 1454 3200 320( 1610 3200 320( 1625 3200 320( 1626 3200 320( 1628 3200 320( 1632 3200 3200 1600 3200 3200 1706 3200 3200 1729 3200 3200 1735 3200 3200 1725 3200 3200 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 0 0 0 0 0 0 0 0 0 0 0 550 0 0 ' 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 55(] 0 0 551] 0 0 55(] 0 0 55~ 0 0 55(] 0 0 55(] 0 0 55(] 0 0 55(~ 0 0 55~ 0 0 55C 0 0 55~ 0 0 55f~ 0 0 55C 283 4450 271 4450 233 4450 234 4525 238 4550 248 4400 288 4500 228 4500 279 4500 285 4500 230 4450 233 4450 273 4450 217 4450 269 4450 253 4450 257 4450 262 4450 50,5O8 3,200 3,200 1,629 3,129 3,194 31 0 o 0 0 o 0 790 79~ 0 782 6501 o 0 550 0 0 550 o .0 402 4400 398 4400 403 4400 403 4575 400 4600 346 4450 397 4550 317 4550 380 4550 385 4550 369 4500 371 4500 374 4500 348 4500 398 4500 379 4500 379 450O 378 4500 7,264 4,550 110 234 4,231 31 11,175 4,600 360 4,267 31 C41-23 shut in due to annular communication problem. C34-23 has developed an annular communication problem. AOGCC notified on 12/12/99. Verbal approval to continue to inject r~ived from Mr. Wondzell on 12/14/99. WATER INJECTION REPORT PLATFORM C December-2000 01-Dec-2000 02-Dec-2000 03-Dec-2000 04-Dec-2000 05-Dec-2000 06-Dec-2000 07-Dec-2000 08-Dec=2000 09-Dec-2000 10-Dec-2000 11-Dec-2000 12-Dec-2000 13-Dec-2000 14-Dec-2000 15-Dec-2000 16-Dec-2000 17-Dec-2000 18-Dec-2000 19-Dec-2000 20-Dec-2000 2 l-Dec-2000 22-Dec-2000 23-Dec-2000 24-Dec-2000 25-Dec-2000 26-De.c-2000 27-Dec-2000 28-Dec-2000 29-Dec-2000 30-I)ec-2000 31 -Dec-2000 TOTAL MAXIMUM AVERAGE # DAYS 01112/2001 C23-23 ACT INJ INJ ANNU 1872 2550 3200 1716 2550 3200 0 2550 320~ 184 2550 320~ 1853 2550 320~ 1961 2550 320~ 1739 3250 325C 468 2500 250~ 166 2500 250( 2048 3250 320( 1899 3250 325C 1867 3250 325C 1839 3250 325C 1817 3250 325( i809 3250 3250 1815 3250 3250 1820 3250 3250 1838 3250 3250 1834 3250 3250 1723 3250 3250 1793 3250 3250 1787 3250 3250 1778 3000 3250 1775 3300 325C 1774 3300 325~ 1444 3300 3250 1723 3250 325~ 1733 3250 325C 1680 3250 325C 1726 3250 325£ 1720 3250 325( 49,201 3,300. 3,25C 1,587 3,063 3,19C 30 C41-23 ACT INJ INJ .ANNU 0 500 54~ 0 500 540 0 500 54~ 0 500 54C 0 500 54C 0 5O0 54C 0 500 52( 0 500 52( 0 500 52f 0 500 52( 0 500 520 0 500 520 0 500 520 0 500 520 0 500 520 0 500 520 0 500 520 0 500 520 0 500 520 0 500 520 0 500 52C 0 500 52¢ 0 500 52¢ 0 500 52C 0 500 52C 0 500 52C 0 500 52C 0 500 52( 0 500 520 0 500 520 0 500 520 0 500 540 0 500 524 0 C24-23 ACT INJ INJ ANNU 389 3400 3425 352 3400 3425 0 3400 3425 76 3400 3425 412 3400 3425 410 3400 3425 406 3500 350~ 409 3500 350~ 404 3500 350~ 402 3500 350( 404 3500 350( 404 3500 350( 403 3500 350( 398 3500 350( 401 3500 350( 4O2 350O 350( 404 350O 350( 406 3500 350( 407 35OO 350( 375 3400 3400 398 3500 3500 398 3500 3500 393 3450 345O 392 3450 3450 395 3450 3450 321 3450 3450 375 3400 3400 371 3400 340(] 365 3400 340~ 371 3400 369 340o 340c 11,412 3,500 3,500 368 3,455 3,46~ 30 C41-23 shut in due to annular communication problem. C34-23 ACT INJ INJ ANNU 1862 3050 3275 1681 3050 3275 0 3050 3275 202 3050 3275 1848 3050 3275 1947 3050 3275 1825 3300 330C 1762 3300 330~ 1728 3500 325C 1729 3500 325C 1740. 3500 325C 1751 3500 325C 1738 3500 325( 1726 3500 325¢ 1726 3500 325( 1730 3500 3250 1734 3500 3250 1746 3500 3250 1740 3500 3250 1611 2950 3150 1724 3500 3200 1711 3200 3200 1698 3300 3200 1689 3450 320~ 1681 3000 320~ 1363 2950 320~ 1611 2950 3150 1635 2950 315~ 1587 2950 315C 1623 2950 315¢ 1614 2950 315C 49,762 3,5OO 3,30~ 1,605 3,242 3,22S 3O C23-26 ACT INS INJ ANNU 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 0 0 o 0 0 0 0 0 o 0 0 0 o . 0 o o 0 0 o o o o o o o o 0 0 o 0 0 o o o o o 0 0 0 0 0 0 C41-26 ACT 1NJ INJ ANNU 0 770 650 0 770 650 0- 770 650 0 770 650 0 770 650 0 770 650 0 775 625 0 775 550 0 77O 55~ 0 770 625 0 770 625 0 770 625 0 770 625 0 770 62.~ 0 770 62.~ 0 770 - 62.~ 0 770 62.' 0 770 625 0 770 625 0 780 625 0 780 625 0 780 625 0 780 625 0 0 780 625 o 0 780 625 0 0 780 625 0 0 780 625 0 780 625 0 780 625 0 780 625 0 780 625 0 780 650 0 774 625 0 C34--23 has developed an annular communication problem. AOGCC notified on 12/12/99. Verbal approval to continue to inject received from Mr. Wondzell on 12/14/99. C44-14RD ACT INJ INJ ANNU 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 55C 0 0 550 0 0 550 0 0 55O 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 55O 0 0 550 0 0 550 0 C24A-23 ACT INJ INJ ANNE 147 3400 C 123 3400 C 0 3400 0 56 3400 0 182 3400 0 180 3400 0 171 3500 141 3500 131 3500 120 3500 154 3500 162 3500 152 3500 145 35OO 138 3500 132 3500 I10 3500 123 3500 237 4100 227 4250 287 4250 263 4250 259 4325 268 4350 247 4400 267 4400 227 4250 201 3350 223 4250 144 3350 198 3400 5,415 4,400 175 3,720 30 257 3500 270 3500 275 3500 _ 275 3500 289 3500 389 4100 395 4350 443 4250 434 4300 450 4350 432 4400 433 4450 423 4450 395 4350 317 2700 363 4350 287 3500 310 3500 9,698 4,450 313 3,734 3O WATER INJECTION REPORT PLATFORM C N ovember.-20,'.K) C23-23 'iiiiii~!i:i:i:i:i:i:i:::!:::::i:!:iii!i!:::i:!:i::::ii ACT 0 [ .. Nov..2(~.~) 02- Nov.2C~K, 03.. NOv. 2 {~-Nov-2~YO 05-.N'ov..20(~) (~-Nov'-2C~30 ffT.Nov-2{~ 08.-Nov-2C~X} 00..'Nov..2CR)0 O-Nov- 1 -Nov.2~ 2-Nov-2~ 4-Nov.2 5-N¢w.2000 6-Nov-2~ t 7-.Nov.-2(~X) 9-Nov: 20-Nov-2~ 22-Nov 23..Nov.2~} 24-Nov..2~ 26-Nov- 27.Nov.2~ 28-Nov-2~) 2q.:Nov..2C~)0 TOT~ M~ AV~GE g DAYS 1807 3300 3300 1788 3300 3300 1815 3300 3300 1799 3300 3300 1795 3300 3300 1804 3300 3300 1806 3300 3300 1780 3300 3300 180g 3300 3300 1800 3300 3300 1726 3300 3300 1698 3250 325~ 1695 3250 325¢ 1718 3250 325~ 1705 3250 325¢ 1687 3250 325C 1702 3250 325C 1710 3250 325( 1694 3250 325( 1707 3250 325C 1690 3250 325( 1693 3250 325( 1688 3250 325( 1693 3250 325( 1694 3250 325( 1711 3250 325( 1695 3250 325( 1301 3250 3250 1704 3250 3250 1767 3300 3300 51,68o 3,300 3,300 1,723 3,270 3,270 30 C41-23 ACT [NJ [NJ ANNU 0 500 52C 0 500 52C 0 500 52C 0 500 52C 0 500 52C 0 500 52C 0 500 52C 0 500 52C 0 500 52( 0 500 52.~ 0 500 52.~ 0 500 52.~ 0 500 52: 0 500 52.~ 0 500 52( 0 500 520 0 500 520 0 500 520 0 500 520 0 500 520 0 500 520 0 500 530 0 500 530 0 500 530 0 500 520 0 500 520 0 500 520 0 500 52G 0 500 535 0 500 52~ 0 500 535 0 500 522 0 C24-23 ACT INJ [NJ ANNU 435 3500 3500 430 3500 3500 436 3500 3500 431 3500 3500 428 3500 3500 430 3500 3500 432 3500 3500 422 3500 3500 433 3500 3500 431 3500 3500 426 3500 3500 424 3500 3500 423 3500 3500 431 3500 3500 427 3500 3500 420 3500 3500 425 3500 3500 426 3500 3500 422 3500 35012 426 3500 35~ 420 3500 35~ 420 3500 35~ 418 35OO 350f 421 3500 350{ 419 3500 350{ 424 350O 350{ 420 3500 350( 321 3500 351X 404 3450 3462.~ 422 3500 350( 12,647 3,5OO 3,5O0 422 3,498 3,499 3O C34-23 C23-26 C41-26 ACT ACT ACT [NJ [NJ ANNU INJ [NJ ANNU [NJ [NJ ANNU 1730 3300 3300 1710 3300 3300 1736 3300 3300 1714 3300 3300 1710 3300 3300 1720 3300 3300 1727 3300 3300 1690 3300 3300 1733 3300 3300 1723 3300 3300 1673 3300 33012 1648 3250 325~ 1643 3250 325¢ 1668 3250 325C 1657 3250 325C 1639 3250 325C 1663 3250 325C 1674 3250 325C 1662 3250 325( 1684 3250 325C 1667 3250 325C 1669 3250 '325( 1667 3500 325( 1676 3550 325C 1684 3500 325( 1708 3500 325( 1693 3500 325( 1297 3500 3250 1769 3275 3250 1683 3300 3300 50,317 3,550 3,300 1,677 3,323 3,270 30 0 0 o o 0 0 0 o 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 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 o 0 0 0 0 0 0 0 0 0 0 0 0 760 600 0 760 600 0 760 600 0 760 600 0 760 600 0 760 600 0 760 600 0 760 600 0 760 600 0 760 600 0 760 600 0 770 600 0 770 600 0 770 600 0 770 625 0 77O 625 0 770 625 0 770 625 0 770 625 0 770 625 0 770 625 0 77O 625 0 770 625 0 770 625 0 770 625 ' 0 770 62~ 0 770 625 0 770 62~ 0 770 62~ 0 760 60( 0 0 770 625 0 0 766 613 0 C44-14RD ACT INJ [NJ ANNU 0 0 550 o 0 550 0 0 550 0 0 550 0 0 550 0 0 55o 0 0 550 0 0 550 0 0 55O, 0 0 550 0 0 550 0 0 55O 0 0 55O 0 0 550 0 0 55O 0 0 55O 0 0 550 0 0 55O 0 0 550 0 0 550 0 0 550 0 0 55O 0 0 550 0 0 550 0 0 55O 0 0 550 0 0 550 0 O 550 0 0 550 0 0 550 0 0 550 0 0 550 0 C24A-23 ACT [NJ [NJ ANNU 108 3500 165 104 3500 165 112 3500 165 116 35® 165 120 3500 165 117 3500 165 118 3500 165 121 3500 165 129 3500 165 126 3500 145 120 3500 145 120 3500 160 127 3500 1~0 116 3500 150 121 3500 155 135 3500 123 3500 155 129 3500 145 137 3500 145 135 3500 145 136 3500 142 132 3450 142 137 3450 140 130 3500 135 135 3500 135 131 3500 135 104 3500 135 151 3500 150 103 3500 175 3,719 3,5O0 175 124 3~97 153 30 12/11/2000 C4 i-23 shut in due tO annular communication problem. C34-23 has developed an annular communication problem. AOG-CC notified on 12/12/99. Verbal approval to continue to inject received from Mr. Wondzell on 12/14/99. RECEIVED DEC 2 1 Z000 Alaska Oil & Gas Cons. Commission ^nchotage WATER INJECTION REPORT PLATFORM C J ufy.2000 C23-23 C41-23 C24-23 C34-23 C23-26 C41-26 C44-14RD ~ C24A-23 C24A- 14 :!:i:i:'i:'i:i:i':i~i:i:!:i:i:i:i: !:i:i:i: ACT ACT ACT ACT ACT ACT ACT ACT C,I ..]ol..2000 192 3400 3400 0 550 490 88 3500 350( 259 3400 340( 0 0 0 0 700 550 0 0 550' 60 3500 14( 166 3500 02-Jul-2000 1665 3400 340~ 0 SSO 49C 465 3500 35002288 3400 3400 0 0 0 0 700 550 0 0 550 183 3500 140 664 3500 03.-Jul~.2t~)0 2063 3400 340(]0 550 49C 454 3500 350(2366 3400 3400 0 0 0 0 700 550 0 0 550 126 3500 140 558 3500 04-$u1-2000 2124 3400 340(] 0 550 49C 452 3500 3500 · 2368 3400 3400 0 0 0 0 700 55(3 0 0 550 112 3500 175 531 3500 05.J~tl..?000 2066 3400 340~ 0 550 49C ' 446 3500 3500 2337 3400 3400 0 0 0 0 700 550 0 0 550 108 3500 175 508 3500 06-J~d-2000 2073 3400 330~ 0 550 48~ 456 3500 3500 2369 3400 3400 0 0 0 0 700 550 0 0 550107 3500 180 509 3500 07..Jul .2tK','0 2047 3400 330C 0 550 48~ 456 3500 3500 2357 3400 3400 0 0 0 0 700 55~ 0 0 550 113 3500 185 482 3500 08 -.l'uI-2 (R3'0 2029 3400 330C 0 550 49¢ 455 3500 3500 2345 3400 3400 0 0 0 0 700 550 0 0 550 107 3500 190 482 3500 09-J ttl..~(E30 2006 3400 330~ 0 550 49C 451 3500 3500 2323 3400 3400 0 0 0 0 700 550 0 0 550106 3500 190 470 3500 10-Jul-2000 1996 3400 330~ 0 550 49C 451 3500 3500 2312 3400 3400 0 0 0 0 700 550 0 0 550 112 3500 200 466 3500 I I ..$ul..2000 1987 3400 330C 0 550 49C 448 3500 35002300 3400 3400 0 0 ~ 0 700 55~ 0 0 550 126 3500 205 443 3500 12 -.l'ul-2t¥,x) 1977 3400 3325 0 550 49C 447 3500 3500 2283 3400 3400 0 0 ~ 0 700 55C 0 0 550129 3500 220 428 3500 13. J~tl..2~')0 1977 3400 332~ 0 550 49C 448 3500 3500 " 2283 3500 3400 0 0 0 0 700 555 0 0 550 130 3500 225 421 3500 14-J~tl-200) 1974 3400 332~ 0 550 49C 449 3500 3500 " 2279 3500 3400 0 0 0 0 700 555 0 0 550 125 3500 225 415 3500 15...h~l.2t)00 1955 3350 335~ 0 550 49( 444 3500 350~ 2258 3500 3400 0 0 ¢ 0 700 55~ 0 0 550 124 3500 235 414 3500 16-Jul-2tx)o 1954 3350 335¢ 0 550 49( 445 3500 350(12255 3500 3400 0 0 C 0 700 55'~ 0 0 550 118 3500 235 413 3500 17.J~d..~(~,^to 1937 3350 335¢ 0 550 49( 442 3500 3500 2238 3500 3400 0 0 ¢ 0 700 55~ 0 0 550 119 3500 235 411 3500 1 ~-Jul-2000 1945 3350 335C 0 550 49( 445 3500 3500 2241 3500 3400 0 0 c 0 700 555 0 0 550 117 3500 235411 3500 19.-Jul.2t.~.~) 1927 3350 335( 0 550 490 440 3500 350~ 2222 3500 3400 0 0 C 0 700 55.~ 0 0 550 118 3500 23¢ 407 . 3500 20-.lul-20~) 1911 3360 332.~ 0 495 495 437 3495 350~ 2200 3500 3400 0 0 c 0 700 56( 0 0 550 119 3495 235 401 3500 21 .JR1..2000 1872 3360 330( 0 500 500 428 3450 3475 2148 3500 340~ 0 0 C 0 700 56( 0 0 550 115 · 3450 24c 390 3500 22-J~tl-2f.~3 1895 3360 330( 0 500 500 436 3450 3495 2167 3150 340~ 0 0 ( 0 705 56( 0 0 550 127 3450 243 387 3525 23-...h. ll. 20(~.~ 1908 3360 3300 0 500 500 441 3450 3495 2180 3150 340~ 0 0 0 705 560 0 0 550 128 3450 243 383 3525 24-.~'ul-2000 1905 3360 3315 0 500 500 441 3495 350~ 2172 3150 3405 0 0 0 700 560 0 0 550 118 3475 24. 25.Jul..2000 1910 3360 3325 0 500 505443 3450 350~ 2170 3175 3415 0 0 0 705 560 0 0 550 117 3475 24, 26-Jttl-201X! 1905 3375 3335 0 500 502442 3495 350C 2157 3200 3425 0 0 0 0 702 560 0 0 550 121 3475 24, 27..$ul..2~.K~.~ 1906 3350 3350 0 500 502 445 3500 350~2153 3400 340~ 0 0 0 0 702 560 0 0 550 139 3500 25~ 353 3500 28-Jul-20~0 1886 3350 3350 0 500 502 441 3500 350( 2124 3400 340( 0 0 0 0 702 56O 0 0 550 140 3500 255i 358 3500 29.Jttl-2000 1931 3350 3350 0 500 502 452 3500 350( 2179 3400 340( 0 0 0 0 702 560 0 0 550126 3500 255 360 3500 30-J~tl-20~) 1917 3350 3350 0 500 502 448 3500 350~ 2155 3400 340( 0 0 0 0 702 560 0 0 550 121 3500 255:360 3500 31 ..Jul..20tX) 1922 3350 3350 0 500 502 451 3500 350~ 2158 3400 340( 0 0 0 0 702 560 0 0 550 129 3500 255 354 3500 TOTAL 58,762 0 13,487 67,646 0 0 0 3,740 13,021 MAXIMUM 3,400 3,400 550 505 3,500 3,500 3,500 3,425 0 0 705 560 0 550 3,500 255 3,550 AVERAGE 1,896 3,375 3,338 0 530 494 435 3,493 3,499 2,182 3,391 3,401 0 0 0 0 701 555 0 0 550 121 3,493 217 420 3,506 , ,#DAYS 31 0 31 31 0 0 0 31 31 08108/2000 .7.41-23 shut in due to annular communication problem. ~4-23 has developed an annular con'mmnication problem. AOGCC notified on 12/12/99. Verbal approval to continue to inj~t r~-ived from Mr. Wondz¢ll on 12/14/99. WATER INJECTION REPORT PLATFORM C .h~ne-2000 C23-23 C4 !-23 C24-23 C34-23 C23-26 C41-26 C44-14RD C24A-23 C24A- 14 01..Jun-2000 0 1300 130(] 0 550 50~ 0 1200 125C 0 800 100( 0 0 0 0 700 550 0 0 550 0 500 410 02-Jun-2(;~'~ 0 1300 130~ 0 550 50~ 0 1200 125C 0 800 100( 0 0 0 0 700 550 0 0 550 0 500 410 03..Ju~-2~) 0 1300 130~ 0 550 50~ 0 1200 125C 0 800 100( 0 0 0 0 700 550 0 0 550 0 500 410 04-Ju~-2000 0 1300 130~ 0 550 50~ 0 1200 125C 0 800 100( 0 0 0 0 700 550 0 0 550 0 500 410 05-J~m-2000 0 1300 130(] 0 550 50~ 0 1200 125C 0 800 1000 0 0 0 0 700 550 0 0 550 0 500 410 06-J~m-20(~) 0 1300 130~ 0 550 50{ 0 1200 125( 0 800 1000 0 0 0 0 700 550 0 0 550 0 500 410 07-.Jut~.-20(~) 0 1300 130~ 0 550 50{ 0 1200 125{ 0 800 1000 0 0 0 0 700 55~ 0 0 550 0 500 410 08-J~m-2000 0 1250 120~ 0 550 495 0 1150 120{ 0 750 975 0 0 0 0 700 55~ 0 0 550 0 255 425 09-J~m..2000 0 1250 120{ 0 550 495 0 1150 120{ 0 750 975 0 0 0 0 700 55~ 0 0 55(~ 0 255 425 lO-J,n-2000 0 1200 120{ 0 555 495 0 1150 120{ 0 740 960 0 0 0 0 695 55(~0 0 550 0 255.430 I I..Jut~..2t~) 0 1200 ! 195 0 555 49'~ 0 1150 120{0 . 700 950 0 0 0 0 700 55~ 0 0 550' 0 205 432 t 2-J~m-2000 0 1175 1175 0 550 48~ 0 1150 I19.~ 0 700 950 0 0 0 0 700 55~ ' 0' 0 5500 200 435 0 0 7.~ 13.-Jtm-2000 0 1175 116~ 0 550 48{ 0 !150 119(0 700 950 0 0 0 0 700 55¢ 0 0 550 0 175 438 0 0 8~ 14-Jtm-2(KK~ 0 1160 115{ 0 550 49{ 0 1140 119(0 700 940 0 0 {~ 0 700 55C 0 0 550 0 150 44(~ 0 0 9~ 15-Jm~..20{~J 0 1160 115( 0 550 49{ 0 1140 119(0 700 940 0 0 ~ 0 700 55C 0 0 550 0 150 44~ 0 0 9~ 16-J~m-2000 0 ! 160 115( 0 550 49{ 0 1140 119(0 700 940 0 0 (~ 0 700 55~ 0 0 550 0 150 44¢ 0 0 9~ 17-J~m..2000 96 1160 1 i5( 0 550 49( 46 1140 1190 . 155 700 9400 0 {~ 0 700 55( 0. 0. 550 35 150 44£ 0 0 e~ 18 -J~m-2¢3'Y,'~ 1533 1160 115( 0 550 49( 332 1140 !190 34 700 94~ 0 0 C 0 700 55( 0 0' 550 206 150 44C 686 0 19..Ju~t.200C~ 2401 1160 115( 0 550 49( 464 !140 1190 2528 700 94{~ 0 0 C 0 700 55( 0 0 550 171 150 44¢ 850 0 20-Jun-2000 2339 3300 330( 0 550 490 488 3450 3450 2486 3350 300~ 0 0 ¢ 0 700 55( 0 0 550 148 3450 345( 578 3500 350~ 2 l-Jim-2000 2270 3300 330( 0 550 490 467 3450 3450 2463 3350 300~ 0 0 { 0 700 55(0 0 550 132 3450 345{ 576 3500 3500 22-Jun-20~'~} 2219 3300 330( 0 .550 490 464 3450 3450 2445 3350 300~ 0 0 ~ 0 700 55( 0 0 550 119 3450 345{ 549 3500 3500 23..Jufl..2qn)O 2210 3350 330( 0 550 490 469 3500 3500 2457 3400 340~ 0 0 C 0 700 55¢ 0 0- 550 122 3450 10{ 537 3500 0 24-Jun-2000 2182 3350 335~ 0 550 490 465 3500 3500 2437 3400 340{ 0 0 ( 0 700 550 0 0, 550 i13 3500 10,~ 516 3500 0 25. J~m-'2000 2162 3350 3350 0 550 490 462 3500 3500 2412 3400 340~ 0 0 ( 0 700 550 0 0 550i15 3500 12(495 3500 0 26-Jtm-20A)0 2141 3350 3350 0 550 490 458 3500 3500 2397 3400 340{ 0 0 ( 0 700 550 0 0 550123 3500 13.~ 476 3500 0 27 .-J mt. 2(",~.~ 1867 3400 3400 0 550 490 404 3500 35002095 3400 340{ 0. 0 ( 0 700 550 0 0 550 92 3500 14( 417 3500 0 28-Jun-2000 0 3400 3400 0 550 490 0 3500 3500 0 3400 340{ 0 0 ( 0 700 550 0 0 5500 3500 14¢ 0 3500 0 29-J~m-~O00 0 3400 3400 0 550 490 0 3500 3500 0 3400 340{ 0 0 0 700 550 0 0 5500 3500 14[ 0 3500 0 30-Jun-2~'~.) 0 3400 3400 0 550 4900 3500 350(]0 3400 340{ 0 0 0 700 550 0 0 5500 3500 140 0 3500 0 TO'I~AL 21,420 0 4,519 21,909 0 0 0 1,376 5,680 MAXIMUM 3,400 3,400 555 500 3,500 3,500 3,400 3,400 0 0 700 550 0 550 3,500 3,450 3,500 3,500 AVERAOE 714 2,007 1,999 0 550 493 151 2,016 2,048 730 1,713 !,8200 0 0 0 700 550 0 0 55046 i,468 649210 1,283 375 #DAYS 11 0 il 11 0 0 0 Il 10 07/10/2000 C41-23 shut in due to annular conmmnication problem. C34-23 has deveiol~ed an annular conm~nicafion problem. AOCsCC notified on 12/12/99. Verbal approval to conl~n~ to inject rei:eived f~xn Mr. Wondzell ~n i 2/14/99. All Platform"C" injectoFs shut-in from May I I thru Jtme 16 du~ to pump failure. · · RECEIVED Alaska Oii& Gas cons· Cornm'~on Anchorage May-2000 0 ! -May-2000 02 .May.2000 03-.May..2000 04-May-2000 05-May-2000 06..May..2000 07-May. 200O 08-May-2000 09-1May-2000 I 0.May-2000 11 ..Ma?2000 12-May-2000 13-May-2000 14-May-2000 15 ..May. 2000 16-May-2000 17-Mayo2000 18.May-2000 19~Ma?2000 20-May-2000 21 -May-2000 22~May..2000 2.3 .M. ay- 2000 24-May-2000 25-May-2000 26.May.2000 2 ?..May-2000 2g-May-2000 29-May-20Cg) 30:May-2000 31 ..May- 2000 TOTAL MAXIMUM AVERAGE # DAYS WATER INJECTION REPORT PLATFORM C , C23-23 C34-23 ,,, C23 -26 C41-23 C24-23 ACT ACT ACT ACT ACT ~J INJ ANNU ~J ~J ANNU ~J ~J ANNU ~J ~J ANNU ~J ~J ANNU . 374 3500 350C 393 3500 350~ 404 35O0 350C 393 3500 350C 388 3500 350~ 385 3500 3500 394 3500 3500 401 3500 35012 397 3500 3500 79 3500 3500 0 1500 1500 0 1400 1450 0 1410 141{ 0 1400 1400 0 1360 139{ 0 1350 1360 0 }350 135{ 0 1350 135{ 0 1350 135{ 0 1350 135¢ 0 1350 135{ 1949 3450 3400 2010 3450 3400 2102 3450 3400 2060 3450 3400 2035 3450 3400 2028 3450 3400 2074 3450 3400 2104 3450 3400 2090 3450 3400 417 3450 3400 0 1500 1650 0 1350 1525 0 1450 1450 0 1200 1400 0 ' 1300 1350 0 1300 1310 0 1200 1275 0 1200 1275 0 1200 1275 0 1200 1275 0 1200 1275 o 0 0 0 0 0 o 0 0 0 0 0 0 o 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 0 1743 3340 3300 1814 3340 3300 1873 3340 3300 1827 3340 3300 1810 3340 3300 1703 3340 3300 1831 3340 3300 1846 3340 3300 1836 3340 '3300 366 3340 3300 0 2100 2050 0 1900 1895 0 1840 1840 0 1750 1760 0 1710 1710 0 1700 1690 0 1650 1640 0 1650 1640 0 1650 1640 0 1650 1640 0 1650 1640 0 500 520 0 500 520 0 500 525 0 500 525 0 500 525 0 500 525 0 500 525 0 500 525 0 500 525 0 500 525 0 550 525 0 550 520 0 550 525 0 550 525 0 550 525 0 560 525 0 550' 52~ 0 550 52~ 0 550 52~ 0 550 52C 0 550 52~ C41-26 ACT INI INJ AN-N'U 0 670 550 0 670 550 0 670 550 0 670 550 0 670 550 0 670 550 0 670 550 0 670 550 0 670 550 0 670 550 C44-14RD ACT INJ INJ ANNU 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 55O 0 0 550 0 0 550 0 0 550 0 0 550 C24A-23 ACT' ' INJ INJ ANNU 113 3500 3C 112 3500 3C 114 3500 3C 113 3500 3¢ 113 3500 3C 113 3500 30 !13 3500 3C 113 - 3500 3¢ 113 3500 3~ 113 3500 3{ 0 680 500 0 675 550 0 675 54~ 0 675 550 0 675 550 0 675 550 0 675 550 0 675 55¢ 0 675 55~ 0 675 55¢ 0 675 55¢ 0 0 550 0 0 550 0 0 550 840 1,500 550 0 0 550 0 0 550 0 0 55O 0 0 55O 0 0 550 340 1,4OO 550 1,020 1,400 550 0 2200 25~ 0 1855 293 0 1700 0 1550 325 0 1440 335 0 1325 345 0 1255 35C 0 1255 35C 0 1255 35C 0 1255 35( 0 1255 35C 0 1650 1640 0 1650 1640 0 1650 1640 0 1400 1400 0 1400 1400 0 1400 1400 0 1350 1350 0 1350 1350 0 1350 1350 0 1300 1300 16,649 3,340 3,300 537 2,166 2,149 10 0 550 52C 0 550 52f 0 550 52C 0 550 51¢ 0 550 51C 0 550 51{ 0 550 50{ 0 550 50{ 0 550 50{ 0 550 50{ 0 1350 135{ 0 1350 135{ 0 1350 135{ 0 1300 130{ 0 1300 130{ 0 1250 125{ 0-' 1250 125( 0 1250 125{ 0 1250 125f 0 1200 125{ 0 560 525 0 534 519 0 3,608 3,500 3,500 116 2,033 2,037 10 0 1200 1275 0 1200 1275 0 1200 1275 0 900 I 10~ 0 ~00 110~ 0 900 1 i 0(~ 0 900 110C 0 900 I 100 0 850 !05C 0 800 1000 18,869 3,450 3,400 609 1,882 1,950 10 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 675 55{ 675 55{ 675 55{ 1150 1000 55f 1250 55~ 1400 1500 55( 1200 55( 700 55f 1~00 550 786 548 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 2,200 1,500 550 73 143 550 3 0 1255 35( 0 1255 35( 0 1255 35( 0 725 38( 0 725 38( 0 500 40{ 0 400 40( 0 400 40~ 0 250 410 0 500 41( !,130 3,500 410 36 1,891 250 10 06/14/2000 C41-23 shut in due to annular communication problem. C34-23 h~s developed an annular communication problem. AOGCC notified on 12/12/99. Verbal approval to continue to inject received from Mr. Wondzell on 12/14/99. All Platform "C" injectors shut-in from Mayl I ~hru today due to pump failure. Pump has been repaired and is cun'ently being installed. WATER INJECTION REPORT PLATFORM C lVlarch-2000 C23-23 C41-23 C24-23 C34-23 C23-26 C41-26 C44-14RD C24A-23 , 01-Mar-2000 1802 3240 3200 0 550 50~ 377 3440 3450 1998 3425 3375 0 50 0 0 645 500 0 0 550 160 4500 02-Mar.2000 1820 3250 3225 0 550 51£ 384 3500 3500 2041 3450 3400 0 0 0 0 640 500 0 0 550 294 4550 03-Mar-2000 1807 3250 3225 0 550 51( 382 3500 3500 2037 3450 3400 0 0 0 0 640 500 0 0 550 248 4600 04-Mar.2000 1924 3350 330( 0 550 51( 386 3500 350(3 2054 3450 3400 0 0 0 0 640 500 0 0 550 72 3500 05-Mar-2000 1940 3350 332C 0 550 51( 385 3500 350(] 2056 3450 3400 0 0 0 0 640 500 0 0 550 124 3500 06-Mar-2000 2794 3150 310( 0 550 51( 380 3500 3500 2021 3425 3400 0 0 0 0 640 500 0 0 550 136 3500 07-Mar-2000 667 3200 315C 0 550 51( 379 3500 3500 2022 3450 3400 0 0 0 0 640 500 0 0 550 143 3500 08-Mar-2000 1637 3150 314~ 0 550 51¢ 384 3500 3500 2044 3450 3400 0 0 0 0 640 500 0 0 550 119 3500 09-Mar-2000 1664 3150 314{~ 0 550 51£ . 388 3500 3500 2082 3450 3400 0 0 0 0 640 500 0 0 550 52 ,2650 I 0-Mar-2000 1652 3150 314C 0 550 51¢ 386 3500 3500 2061 3450 3400 0 0 0 0 640 50( 0 0 550 19 2650 I i-Mar-2000 1644 3150 3140 0 550 51(~ 383 3500 3500 2049 3450 340( 0 0 (~ 0 640 50( 0 0 550 0 2650 i 2-Mar-2000 1 646 3150 3140 0 550 5 I¢ 384 3500 3500 2024 3450 340( 0 0 0 0 640 50( 0 0 550 0 2650 3-Mar-2000 i 634 3 ! 50 3140 0 550 5 lC 388 3500 3500 1966 3450 340( 0 0 ( 0 640 50( 0 0 550 0 2650 4-Mar-2000 i 590 3150 3140 0 550 5 I{~ 370 3500 3500 1896 3450 340( 0 0 ( 0 640 50( 0 0 550 0 2650 15-Mar-2000 1617 3150 3140 0 550 510 380 3500 3500 1917 3450 340C 0 0 C 0 640 50( 0 0 550 138 3500 6-Mar-2000 1621 3150 3150 0 550 510 382 3500 3500 i 943 3420 3400 0 0 C 0 640 50C 0 0 550 174 3800 17-Mar-2000 1771 3275 3230 0 550 510 393 3500 350( 2002 3440 3400 0 0 I~ 0 640 500 0 0 550 248 4050 18-Mar-2000 1761 3275 3240 0 550 510 391 3500 350 2009 3440 3400 0 0 0 0 640 500 0 0 550 240 4100 ! 9-Mar-2000 1787 3300 3250 0 550 510 388 3500 350( 2003 3450 3400 0 0 C 0 640 500 0 0 550 243 4250 20-Mar-2000 1778 3300 3250 0 550 515 387 3500 350( 2006 3450 3400 0 0 ~ 0 640 500 0 0 550 99 3500 2 l-Mar-2000 1790 3350 3300 0 550 510 386 3500 350( 2001 3450 3400 0 0 1~ 0 640 500 0 0 550 138 3500 22-Mnr-2000 1846 3350 3300 0 550 510 393 ' 3500 350( 2040 3450 3400 0 0 ~ 0 640 500 0 0 550 142 3480 23-Mar-2000 1805 3350 3300 0 550 510 385 3500 350( 1994. 3450 ' 3400 0 0 ~ 0 640 50( 0 0 550 153 4000 24-Mar-2000 1814 3350 3300 0 550 510 387 3500 350( 2009 3450 3400 0 0 ~ 0 640 500 0 0 550 310 4300 25-Mar-2000 1801 3300 3300 0 550 510 384 3500 350( 1997 3400 3400 0 0 1~ 0 640 500 0 0 550 303 4500 . 26-Mnr-2000 1812 3300 3300 0 550 510 387 3500 350( 2014 3400 3400 0 0 {~ 0 500 500 0 0 550~ 303 4500 27-Mar-2000 1777 3300 3300 0 520 510 386 3500 350( 1953 3400 3400 0 0 I~ 0 500 500(] 0 0 550 161 4500 28-Mar-2000 1718 3300 3200 0 520 500 '. 390 3500 3500 1975 ' 3400 3400 0 0 l~ 0 500 500 0 0 550 97 3500 29-Mar-2000 1704 3300 3200 0 520 500 391 3500 350( 1962 3400 3400 0 0 ~ 0 500 500 0 0 5501 126 3500 30-Mar-2000 1748 3250 3250 0 550 500 " 386 3500 350( 1958 3450 340~ 0 0 ~ 0 640 500 0 0 550[ 147 3500 3 I-Mar-2000 .. 1687 3300 3275 0 550 500 Ii 375 3500 350( 1866 3425 3400 0 0 ~ 0 640 500 0 0 550 150 3500 TOTAL 54,058 0 I 1,927 62,000 0 0 0 4,539 MAXIMUM 3,350 3,320 550 $15 3,500 3,500 3,:150 3,400 50 0 645 500 0 550 4,600 AVERAGE i,744 3,250 3,219 0 547 509 385 3,498 3,498 2,000 3,438 3,399 0' 2 0 0 622 500 0 O 550 146 3,646 # DA..YS 31 0 31 .... 31 0 0 0 27 41-23 shut in due to annular communication problem. 34-23 has developed an annular communication problem. AOGCC notified on 12/12/99. Verbal approval Io cundnue to inject r~ved from Mr. Wondzeli on 12/14/99. RECEIVED Alaska Oil & Gas Cons. CommJs~3a Anchorage WATER INJECTION REPORT PLATFORM C April-2000 C23-23 C41-23 C24.'~a C34-23 C23-26 C4~-26 C44-14RD C24A-23 ~ ~ ~~ ~ ~::~ ~J ~J A~U ~J ~J A~U ~J ~J A~U ~J ~J A~U ~J ~J A~U ~J ~J A~U ~J ~J A~ ~J ~J A~U~ 01-Apr-20~ 1817 33~ ~3~ 0 550 520 ~94 ~ ~ 1982 ~450 34~ 0 0 0 0 ~0 ~ 0 0 5'50 150 35~ 02-Apr-2~0 1762 3300 332~ 0 550 520 380 35~ 35~ 1932 3450 340~ 0 0 ~ 0 640 5~ 0 0 550 150 3500 55[ 03-Apr-20~ 1834 33~ 332~ 0 550 5 ! 5 397 3500 35~ 2019 3450 34~ 0 0 ~ 0 650 500 0 0. 550 150 35~ 55 ~-Apr-2~ i 850 33~ 3325 0 550 515 399 35~ 35~ 2038 3450 3~ 0 0 ~ 0 650 500 0 0 550 150 3500 60 05-Apr-2~ 1858 33~ 332~ 0 550 515 401 35~ 35~ 2050 3450 340~ 0 0 ~ 0 650 5~ 0 0 550 150 3500 60 ~Apr-2~0 1839 33~ 3325 0 550 5 i 5 397 35~ 35~ 2025 3450 340~ 0 0 ~ 0 650 5~ 0 0 550 150 35~ 60 07-Apr-2~ 1841 33~ 332~ 0 550 515 395 3~ 35~ 2024 3450 340G 0 0 ~ 0 650 5~ 0 0 550 150 35~ 60 08-Apr-2~ 1837 3300 3325 0 550 515 3~ 35~ 35~ 2025 3450 34~ 0 0 ~ 0 650 5~ 0 0 550 107 35~ 60 09-Apr-2~ 1846 33~ 332~ 0 550 515 3~ 35~ 35~ 2036 3450 340~ 0 0 ~ 0 650 500 0 0 550 108 35~ 60 10-Apr-20~ 1826 33~ 3325 0 550 515 395 3500 35~ 20~ 3450 34~ 0 0 ~ 0 650 5~ 0 0 550 108 35~ 60 -Apr-2~ 1838 3300 332~ 0 550 515 395 35~ 35~ 2025 3450 34~ · 0 0 ~ 0 650 5~ 0 0 550 108 35~ 60 12-Apr-20~ 1838 33~ 332~ 0 550 520 393 35~ ' 35~ 2024 3450 34~ 0 0 ~ 0 650 5~ 0 0 550 107 35~ 65 13-Apr-2~ 1823 33~ 335C 0 5~0 52~ 392 35~ 35~ 2016 34~0 34~ 0 0 0 0 650 5~ 0 0 550 107 3500 6~ 14-Apr-2~ 1833 3375 335( 0 550 525 395 35~ 35~ 2023 35~ 3420 0 0 ~ 0 650 500 0 0 550 107 3500 15-Apr-2~ 18~ 3375 335C 0 550 52~ 389 35~ · ~5~ 1954 35~ 3420 0 0 0 0 650 5~ 0 0 550 108 3500 16-Apr-2~ 1784 3375 335C 0 550 52Y ~83 35~ 35~ 1933 ~5~ 3420 0 0 0 0 650 500 0 0 550 108 3500 17-Apr-2~ 1779 3350 33~ 0 550 51~ 382 3450 345~ 19~4 3450 34~ 0 0 0 0 ,650 5~ 0 0 550 107 3450 i 8-Apr-2~ 1774 3350 33~ 0 550 51( 3~1 3450 345C 1932 ~450 34~ 0 0 0 0 650 5~ 0 0 550 110 3450 19-Apr-2~ 1785 3~50 33~ 0 550 52C ~89 3450 ~45~ 1919 34~0 3375 0 0 0 0 650 ~ 0 0 550 108 3450 20-Apr-2~ 1783 3350 3~ 0 550 52~ 387 3450 345C 1926 3450 3375 0 0 0 0 650 5~ 0 0 550 i 13 35~ 21-Apr-2~ 1293 3350 ~3~ 0 550 52C 288 3450 ~45~ 13~ 3450 3375 0 0 0 0 ~e~ - 0 550 80 35~ 4C 22-Apr-2~ 1878 3350 33~ 0 550 52~ 402 ~450 345~ 2010 ~450 3375 .O 0 550 147 35~ 23-Apr-2~ 1622 3350 3~ 0 550 52C 352 3450 ~45~ ~e ' - 0 550 112 35~ 4C 24-Apr-2~ 0 21~ 33~ 0 550 52C 0 550 0 23~ 4C 25-Apr-2~ 0 0 33~ 0 5~ 52C 0 550 0 0 4C 26-Apr-2~ 459 0 33~ 0 5~ 52( ! I 0 550 I 12 0 27*Apr-2~ 1953 3325 3275 0 5~ 52C · 39~ 0 550 1 i 3 35~ 2~ 29-A~-2~ 18~ 3340 33~ 0 5~ 52( 3~ ~~~v~ --~ 0 550 113 35~ 3C 30-Apr-2~ 1848 3340 33~ 0 5~ 52~ 3~ ~ 0 5501 113 35~ 3C M~I~M 3,375 3,350 550 525 ~ 550 3,5~ 65 AVENGE 1,639 3,~ 3,315 0 540 519 353 ~ ~~ 550 I 12 3,222 49 DAYS 28 o 28 2S 05/10/2000 41-23 shut in due to annular communication problem. Cn.g¥¢~ 34-23 has developed an annular communication problem. AOGCC notified on 12/12/99. Verbal approval to conlh :bruary-2000 OI-Febo2000 02-Feb-2000 03 -Feb-2000 04-Feb-2000 05-Feb-2000 06-Feb.2000 07-Feb-2000 08-Feb-2000 09-Feb-2000 I 0-Feb-2000 i l-Feb-2000 12-Feb-2000' ! 3-Feb-2000 14-Feb-2000 15-Feb-2000 ! 6-Feb-2000 17-Feb-2000 18-Feb-2000 ! 9-Feb-2000 20-Feb-2000 21 -Feb-2000 22-Feb-2000 23-Feb-2000 24-Feb-2000 25-Feb-2000 26-Feb-2000 27-Feb-2000 28-Feb-2000 29-Feb-2000 TOTAL MAXIMUM AVERAGE . ...-,-' # DAYS '" · 03/09/2000 WATER INJECTION REPORT PLATFORM C C23-23 C41-23 C24-23 C34-23 C23-26 C41-26 C44-14RD C24A-23 · ,, ACT ,, ACT ACT ACT ACT ACT ACT ACT INJ INJ ANNU [NJ INI ANNU INJ [NJ ANNU INJ INJ ANNU [NJ INJ ANNU [NJ INJ ANNU [NJ [NJ ANNU [NJ [NJ .. ... O 3 ! 75 317! 0 575 532 373 3475 349C 1926. 3450 340~ 0 50 0 0 640 500 0 0 .550 160 4500 0 0 ' 1770 0 570 528 . 375 3480 349~ ' 1930 3460 340~ 0 50 0 O 640 500 O 0 550 294 4550 0 0 1750 0 575 530 380 3500 350( 1952 3450 3425 0 0 0 O 640 500 0 0 550 248 4600 0 0 1700 0 570 530 381 3500 350C 1948 3450 342~ O O 0 0 640 500 0 0 550 72 3500 0 0 170( 0 560 525 378 3500 350C 1934 3450 3420 0 0 0 0 640 500 0 0 550 124 3500 0 1600 1675 0 560 520 377 3500 350C 1933 3450 3425 0 0 0 0 640 500 0 0 550 136 3500 0 1600 165( 0 560 52( 378 3500 350C 1926 3450 3425 0 O 0 0 640 500 O 0 550 143 3500 0 i 600 162.~ 0 560 52{ 305 3500 350~ 1557 3450 3425 0 0 0 0 640 500 0 0 550 I 19 3500 0 1600 160 0 520 52( 341 3500 350C 33 2900 3425 0 0 0 0 640 500 O O 550 52 2650 0 16OO 160( O 520 52( 401 3500 350C 2047 3450 3425 0 0 0 O 640 500 0 0 550 19 2650 0 1600 160( O 520 52( 379 3500 350~ 2036 3470 3425 0 0 0 0 640 500 O O 550 O 2650 0 1600 160( 0 520 $2{ 391 3500 350~ 2072 3470 3420 0 0 0 0 640 500 O O 550 0 2650 0 1600 160( 0 520 52C 391 3500 350~ 2074 3450 3420 0 0 0 0 640 500 0 0 550 0 2650 0 1600 ! 60C 0 520 52C 382 3500 350~ 2026 3450 ' 3420 0 0 0 0 640 500 O 0 550 0 2650 0 1600 160~ 0 520 52C 381 3500 3500 1991 3500 3420 0 0 0 ' 0 640 500 0 0 550 138 3500 0 1450 1480 0 550 51~ 382 3500 3500 2012 3470 3420 0 O ( O 640 50( 0 0 550 174 3800 O 15OO 148~ 0 550 512 382-' 3490 3500 201i . 3460 · 340( 0 50 C 0 645 50( 0 0 550 248 4050 0 1500 1500 0 550 510 375 3485 3490 1973 3450 340( 0 50 C 0 648 50C 0 0 550 240 4100 0 ! 500 1475 0 550 5 i 0 377 3470 3475 1989 3450 340( 0 50 C O 647 50( 0 0 550 243 4250 0 1450 1450 0 550 510 380 3485 348.~ 1982 3450 340( 0 50 1~ 0 650 50~ O 0 550 99 3500 0 1450 1450 O 550 510 384 3485 348.~ 1999 3450 340( 0 50 0 0 650 50~ 0 0 550 138 3500 0 1450 1420 0 550 510 382 3475 · 359( 1993 3450 340~ 0 50 0 '0 650 50~ O 0 550 142 3480 O 1400 1400 O 550 508 328 3475 349( 1653 3450 340~ 0 50 0 O 650 50~ 0 0 550 153 4000 2066 3200 1400 0 550 508 382 3500 349( 2002 3500 340C 0 50 0 0 650 50~ 0 0 550 3 I0 . 4300 1998 3200 1400 0 550 50! 375 3500 349( 1994 3500 340~ 0 50 0 0 650 50~ 0 0 550 303 4500 1919 3200 1400 0 550 508 375 3500 349( 1999 3500 340C 0 50 .0 0 650 50~ 0 0 550 303 4500 1882 3200 1400 0 550 508 377 3500 3490 2008 3500 340C 0 50 C 0 650 50~ 0 0 550 161 4500 1835 3200 1400 0 550 508 373 3500 3490 1992 3500 340~ 0 50 0 0 650 50~ 0 0 550 97 3500 181 ! 3200 1400 0 550 508 376 3500 3490 2003 3500 340( 0 50 (~ 0 650 50~ 0 0 550 126 3500 , I 1,51 i 0 10,861 54,995 0 ' 0 O 4,242 3,200 3,175 575 532 ' 3,500 3,590 3,500 3,425 50 0 650 500 0 550 4,600 397 1,727 1,597 0 547 516 375 3,494 3,498 1,896 3,446 3,411 0 26 0 O 644 500 O 0 550 146 3,656 6 0 29 29 0 0 0 25 shut in due to annular ~ommunicafion problem. has developed an annular communication problem. AOGCC notified on 12/12J99. Verbal approval .m oonti~ue to inject received from Mr. Wondzell on 12/14/99. down fo~ flmge repaks. WATER INJECTION REPORT PLATFORM C Janua~-2000 C23-23 C41-23 C24-23 C34-23 C23-26 C41-26 C44-14RD C24A-23 01-Jan-2000 1428 3190 3075 0 580 650 395 3500 3500 1950 3560 3425 0 "50 C 0 650 45C 0 0 550 175 3500 02-Jan-2000 1433 3190 3075 0 580 65~ 396 3500 3500 1955 3560 3425 0 50 ~ 0 650 45~ 0 0 550 175 3500 03-Jan-2000 1419 3190 3075 0 580 650 391 3500 3500 1-931 3560 3425 0 50 ~ 0 650 45C 0 0 550 173 3500 04-Jan-2000 1429 3190 3075 0 580 65C 393 3500 3500 1942 3560 3425 0 50 ~ 0 650 45¢ 0 0 550 174 3500 05-Jan,2000 1427 3190 3075 0 580 650 392 3500 3500 1940. 3560 3435 0 50 ~ 0 630 45~ 0 0 '550 174 3500 06-Jan-2000 1421 3200 3075 0 580 65~ 390 3500 3500 1910 3500 3425 0 0 C 0 630 45C 0 ~ 550 173 3500 07-Jan-2000 1406 3200 3075 0 580 650 387 3500 3500 78 2300 1950 0 0 ~ 0 630 45C 0 0 550 173 3500 08-Jan-2000 1392 3200 3075 .0 580 650 381 3500 3500 0 2300 1950 0 0 ' C 0 630 45C 0 0 550 171 3500 09-Jan-2000 1389 3200 3100 0 525 650 381 3500 3500 0 '1900 1750 0 0 0 0 630 450 0 0 550 171 3500 10-Jan-2000 1384 3200 3150 0 530 530 381 3500 3500 352 1750 1700 0 0 0 0 630 50C 0 0 550 171 3500 II-Jan-2000 1386 3200 3150 0 540 530 381 3500 3500 2155 3450 3400 0 0 0 0 640 500 0 0 550 172 3500 12-Jan-2000 1398 3200 3150 0 575 535 382 3500 3500 2100 13460 3400 0 0 0 0 640 500 0 0 550 173 3500 13-Jan.2000 1396 3200 3150 0 575 535 379 3500 3500 2079 3460 .3400 0 0 0 0 640 500 0 0 550 169 3500 14.Jan-2000 . 1411 3200 3150 0 575 535 383 3500 3500 2088 3460 3400 0 0 0 0 640 500 0 0 550 172 3500 15-Jan-2000 1407 3200 3150 0 575 535 381 3500 3500 2069 3460 3400 0 0 0 0 640 500 0 0 550 170 3500 16-Jan-2000 1410 3200 3150 0 575 535 382 3500 3500 ' 2064 3460 .3400 0 0 0 0 640 500 0 0 550 171 3500 17-Jan-2000 1408 3200 315¢ 0 575 535 380 3500 350( 2054 3460 3400 0 '0 0 0 640 500 0 0 550 169 3500 18-Jan-2000 1'405 3200 3150 0 575 535 383 3500 3500 2050 3460 3400 0 0 0 0 640 500 0 0 550 170 3500 19-Jan-2000 1410 3200 315( 0 575 540 382 3500 350( 2049 3500 3425 0 0 0 0 640 500 0 0 550 170 3500 20-Jan-2000 1406 3200 315C 0 575 532 381 3500 350( 2031 3465 3410 0 50 0 0' 640 500 0 0 550 167 3500 21-Jan-2000 1399 3200 315C 0 575 522 379 3500 350( 2020 3475 3425 0 50 0 0 640 500 0 0 550 167 3500 22-$an-2000 1408 3180 3143 0 575 515 381 3490 350( 2030 3460 3410 0 50 0 0 640 500 0 0 550 168 3500 23-Jan-2000 1417 3190 315C 0 575 538 383 3500 350( 2039 3470 342~ 0 50 0 0 640 500 0 0 550 168 3500 24-$an-2000 1388 3175 3173 0 575 538 375 3490 350( 1986 3450 3410 0 50 0 0 .640 500 0 0 550 163 3500 254an-2000 1392 3175 3173 0 575 538 376 3470 347~ 1988 3450 3400 0 50 0 0 640 500 0 0 550 166 3475 26-Jan-2000 585 3175 317~ 0 575 532 374 3475 349( 1971 3450 3400 0 50 0 0 640 500 0 0 550 162 3490 27-Jan-2000 0 3175 317~ 0 575 532 368 3475 349( 1937 3450 3400 0 50 0 0 640 500 0 0 550 238 4500 28-Jan-2000 0 3175 317~ 0 575 532 370 3475 349( 1937. 3450 3400! 0 50 0 0 640 500 0 0 550 370 4500 29-$an-2000 0 3175 317~ 0 575 532 368 3475 349( 1925 3450 3400 0 50 0 0 640 500 0 0 550 331 4500 30~an-2000 0 3175 3173 0 575 532 370 3475 349( 1926 3450 3400 0 50 0 0 640 500 0 0 550 302 4500 31-Jan-2000 0 3175 317~ 0 575 532 370 3475 349( 1918 3450 3400 0 50 0 0 640 500 0 0 550 419 4500 TOTAL 35,754 0 I 1,8 ! 5 54,474 0 0 0 6,087 MAXIMUM 3,200 3,175 580 650 3,500 3,500 3,560 3,435 50 0 650 500 0 550 4,500 AVERAGE 1,153 3,191 3,135 0 572 567 381 3,494 3,497 1,757 3,296 3,207 0 27 0 0 639 485 0 0 550 196 3,660 , , # DAYS 26 0 31 29 0 0 0 31 ¢ 1-23 shut in due to annular communication problem. 34-23 has developed an annular communication problem. AOGCC notified on 12/12/99. Verbal approval to continue to inject received from Mr. Wondz~l on 12/14/99. 23-23 down for f~ve days due to flange repairs and expected to be back online in mid-February. 34-23 shut in for two days for survey. WATER INJECTION REPORT PLATFORM C · O(:lol~e,-~'..21,~00 C23-23 C41-23 C24-23 C34-23 C23-26 C4 ] -26 C44- ] 4RD C24A-23 C24A- 14 :':':':':':':':::":':':':':':':': ' :':':':':':':'! ACT ACT ACT ACT ACT ACT ACT ACT ACT ::: 0/I~..E~&:NO~[~S :i:: :::i: i: i: i:i: i: i: i :i: il [NJ [NJ ANNU INJ I'NJ ANNU [NJ [NJ ANNU [NJ [NJ ANNU [NJ [NJ ANNU [NJ INJ ANNU I'NJ [NJ ANNU [NJ [NJ AN'NU [NJ INJ ANNU 01-Ocl--2000 1879 3350 33000 500 5]5 422 3450 345C 1824 3350 330(] 0 0 0 0 750 60{ 0 ~)' 550 80 3450 225 344 3450 0 02-Oc~-2(XX; 1861 3350 33000 500 51.t 420 3450 345C 1813 3500 3301~ 0 0 I~ 0 750 60{ 0 0 550 74 3450 225 34l 3500 03-Oc1:-2000 1886 3450 33000 500 511 426 3450 345C 1839 3500 33000 0 I~ 0 750 60{ 0 0 550 71 3450 21l~ 341 3500 04-Oc~.2000 1852 3450 33000 500 511 416 3450 345( 1798 3500 330{0 0 (] 0 750 60{ 0 · 0 550 61 3450 211 337 3500 (;'5 -Ocl- .'2000 1864 3450 33000" 500 511 419 3450 345C 1812 3500 33000 0 0 0 750 60{ 0 0 550 77 3450 21C 343 3500 ~.}6-O¢:~-2~)0 1658 3350 32000 500 51( 411 3450 345( 1812 3350 330¢0 0 (~ 0 745 60{ 0 0 550 86 3450 23( 329 3500 ¢ · 0'?-Ocl-2000 1830 3450 3300 0 500 511 409 3450 345( 1771 3500 330{0 0 0 0 750 60{ 0 0 550 68 3450 21£ 308 3500 08-O¢a.2000 1837 3450 3300 0 500 51( 410 3450 345( 1773 3500 330{ 0 0 (~ 0 750 60( 0 0 55067 3450 21( 306 3500 C 09-Ocl-2 (,'.~Xi 1854 3450 3300 0 500 511 414 3450 345C 1785 3500 330~0 0 .l~ 0 750 60{ 0 0 550 80 3450 21C 312 3500 I o-Oct.2~)o 1839 3450 3300 0 500 510 411 3450 345( 1767 3500 330{0 0 C 0 750 60( 0 0 550 99 3450 . 21( 316 3500 C I l-Ocl-2f:~30 1844 3450 3300 0 500 511 413 3450 345( 1775 3500 330{ 0 0 ~ 0 750 60{ 0 0 550 100 3450 21c 318 3500 c ! 2-(:)c~-2000 1871 3350 33000 500 515 418 3450 345( 1803 3500 330{0 0 c 0 750 60( 0 0 550 83 3450 185 312 3500 c 13-Oc1-2000 1896 3350 33000 500 515 427 3450 345( 1835 3500 330{0 0 c 0 750 60( 0 0 550 73 3450 18.s 311 3500 c 14-Oc~.2000 1870 3350 33000 500 515 423 3450 345( 1817 3500 330(0 0 ( 0 750 600 0 0 550 78' 3450 185i 307 3500 15-Oct-21~,)0 1881 3350 33000 500 510 424 3450 345( 1824 3500 330{0 0 c 0 750 60{ 0 0 550 74 3450 180 306 3500 c 16-(.)ct.200(.~ 1791 3350 33000 500 ·510 423 3450 345( 1730 3500 330{0 0 c 0 750 600 0 0 550 72 3450 180 306 3500 C 1 '?-Oc1-2(.~30 1783 3300 32000 500 515 427 3450 345( 1717 3500 325(0 0 ( 0 750 600 0 0 550 70 3450 188 308 3500 C t 8..Oc~.2000 1772 3300 3200 0 500 515 424 3450 345( 1705 3500 325(0 0 0 750 600 0 0 550 70 3450 188, 309 3500 19-Ocl-2000 1783 3300 320~0 500 515 426 3450 3450 1713 3500 325(0 0 0 750 600 0 0 550 70 3450 188 271 3500 20-C')ct.2C-O0 1794 3300 3200 0 500 515 429 3450 3450 1717 3500 325( 0 0 0 750 600 0 0 550 68 3450 188 345 3500 21-Ocl-2000 1766 3300 3200 0 500 515 422 3450 3450 1694 3500 325( 0 0 0 750 600 0 0 55074 3450 188 302 3500 22-O¢:~-20~X1 1747 3300 3200 0 500 515 416 3450 3450 1669 3500 325( 0 0 0 750 600 0 0 550103 3450 188298 3500 23-Oc1-2000 1788 3300 320~ 0 500 515 426 3450 3450 1708 3500 3251 0 0 0 750 600 0 0 550 86 3450 188 259 3500 24-Oc~.2(X)0 1782 3300 320C 0 500 515 428 3450 3450 1704 3500 325( 0 0 0 0 750 600 0 0 550 94 3450 188 197 3500 ~5-Oc1-2000 1802 3300 330(] 0 500 520 432 3500 3500 1723 3300 33000 0 0 0 760 600 0 0 550 117 3500 185 256 3400 0 26-(:)c~.2(X)0 1780 3300 330C0 500 520 426 3500 3500 1703 3500 3300 0 0 0 0 760 600 0 0 550 100 3500 190 284 3500 0 27-Ocl-2000 1785 3300 32750 500 52(~ 426 3450 3450 1704 3300 33000 0 0 0 760 60(] 0 0 550 104 3450 190 281 3500 0 28-C)ct-20(X~ 1796 3300 330~0 500 520 430 3500 3500 1712 3300 33000 0 0 0 760 600 0 0 550 107 3500 185 278 3500 0 29-Oct-2(~,)0 1864 3300 330{0 500 52(~ 446 3500 3500 1777 3300 33000 ' 0 0 0 760 60~ 0 0 55(~ · 105 3500 185 294 3500 0 30-Oc~-2(x)0 1767 3300 330~ 0 500 520 422 3500 35001683 3300 3300 0 0 0 0 760 60~ 0 0 550 103 3500 175 280 3500 0 31 -Ocl-2f,~30 1782 3300 320( 0 500 515428 3450 3450 1704 3500 3250 0 0 0 0 750 60~ 94 3450 185 197 3500 TOTAL 56,304 0 13,094 54,41.1 0 0 0 2,608 9,296 MAXIMUM 3,450 3,300 500 520 3,500 3,500 3,500 3,300 0 0 760 600 0 550 3,500 230 3,500 0 AVERAGE 1,816 3,352 3,267 0 500 ' 514 422 3,458 3,458 1,755 3,458 3,285 0 0 0 0 752 600 0 0 55084 3,458 196300 3,495 0 # D,AYS 31 0 31 31 0 0 0 31 31 1 i/14/2000 · 41-23 shut in duc to annular comnmication problem. 14-23 has devcloped an annular cnnmmnication problen~ AOGCC notified on 12/12/99. Verbal approval to continue to inject received from Mr. Wondzeli on 12/14/99. WATER INJECTION REPORT PLATFORM C A ~.~ ~:..'..2 (~'~ C23-23 C41 ~23 C24-23 C34-23 C23-26 C41-26 C44-14RD C24A-23 C24A- 14 ~!?:i~!i? ~:i~!~:i:?!i:?:!~!~?"~:!!:i~'! ACT ACT ACT ACT ACT ACT ACT ACT ACT. :::::::::::::::::::::::::::::::::: o~ ;,,~...'~c~oo '19i6 3350 335( 0 500 50~ 449 35® 3500 2149 3400 3400 0 15 {] 0 702 56c 0 0 550 126 3500 255 3'58' 02-At~g- 2 f)-'.~ 1905 3350 335( 0 500 502 446 3500 3500 2131 3400 3400 0 15 (~ 0 702 56C 0 0 550 130 3500 255 347 3500 03..,,\ u.o_..20:~.~ 1931 3350 335( 0 500 · 502 . 442 3500 3500 2146 3400 3400 0 15 {] 0 702 56C 0 0 550 123 3500 190350 3500 04 .:x.~.,...20'.~) 2026 3350 3350] 0 500 502! 445 3500 3500 2151 3400 3400 0 15 {] 0 702 56C 0 0 550 128 3500 200 329 3500 05.A~g..?: 000 2018 3350 3400 0 500 510 446 3500 3500 2151 3400 3450 0 15 C 0 702 55C 0 0 550 124 3500 200 335 3500 0(.,-A ~. 20..?,) 2000 3350 3400 0 500 510 443 3500 3500 2135 3400 3450 0 15 C 0 702 55C 0 0 550 123 3500 250 329 3500 0 '.:--.,\ Lt,.o.. -.~ t.~00 1975 3350 3400 0 500 510 437 3500 3500 2104 3400 3450 0 15 C 0 702 55C 0 0 550 135 3500 260322 3500 08- .\u,~-.2000 1982 3350 340( 0 500 510 438 3500 3500 2106 3400 3450 0 15 C 0 702 55C 0 0 550 135 3500 265 322 3500 09 ..,'-, ~g...~ 0~0 1957 3350 340( 0 500 510 432 3500 3500 2078 3400 3450 0 15 C 0 702 55C 0 0 550 128 3500 260 321 3500 1,'~-A~,,,.-'~¢~ ' ~ 1969 3350 3400 0 500 510 435 3500 3500 2085 3400 3450 0 15 C 0 702 55C 0 0 550 130 3500 260325 3500 I 1 ..,'\ug.20~.~ 1956 3350 3400 0 500 510 433 3500 350(] 2073 3400 3450 0 15 C 0 702 55( 0 0 550 129 3500 260323 3500 12 -:\ ug-.2iY,~ 1987 3550 3400 0 500 510 438 3500 350~ 2108 3400 3450 0 15 £ 0 702 55( 0 0 550 139 3500 260 323 3500 13 ..A ~t~..200,~ 38 3350 340( 0 500 510 il 3500 3500 37 3400 3450 0 15 c 0 702 55( 0 0 550 23 3500 260 20 3500 14-Aug-200.0 1173 3250 3250 0 500 510 301 3500 ' 350C 1048 3300 3300 0 15 C 0 702 55( 0 0 550 125 3500 260 343 3400 I .$.-,,\ ug .20 ')(~ 1965 3300 3300 0 500 510 488 3500 350(] 1944 3300 3300 0 15 { 0 702 55( 0 0 550 145 3500 260 405 3500 16-A~.,.-20()0 1909 3300 3300 0 500 510 475 3500 350(] 1938 3300 3300 0 15 C 0 702 55( 0 0 550 159 3500 260 363 3500 I ? · A~g,..2 ('r,'~0 '1900 3350 3300 0 500 510 475 3500 350~ 1941 3300 5325 0 15 ( 0 720 575! 0 0 550145 3500 265 356 3500 18-,e~t~g-'2C~)0 243 3350 3300 0 500 510 62 3500 . 350~ 248 3300 3325 0 15 0 720 57.~ 0 0 550 20 3500 265 47 3500 19--Aug.20(K~ 2079 3350 3300 0 500 510 481 3500 350~ 2008 3300 330~ 0 15 0 720 575 0 0 550 164 3500 25C 441 3500 20-:\ug-20()0 1949 3350 3300 0 500 510 460 3500 350~1982 3300 330~ 0 15 (~0 720 575 0 0 550 140 3500 25¢ 370 3500 21 .At~g..2000 1930 3375 3325 0 500 510 458 3500 350C 1973 3325 3325 0 0 ' 0 0 720 575 0 0 55~ 143 3500 255 356 3500 2~-^ug-2000 1919 3375 3325 0 500 510 458 3500 35~ 1972 3325 3325 0 0 0 0 720 575 0 0 550,141 3500 255 352 3500 23..Aug..20~) 1920 3375 3325 0 500 51(~458 3500 350( 1970 3325 3325 0 0 0 0 720 575 0 0 550 144 3500 25.~345 3500 24-Aug-2000 1895 3375 3325 0 500 51¢ 453 3500 350( 1947 3325 3325 0 0 0 0 720 575 0 0 550 135 3500 255 347 3500 ~5..A~,g..20~tO 1895 3375 3325 0 500 51~ 452 3500 350(1943 3325 3325 0 0 0 0 720 575 0 0 550 127 3500 25.~345 3500 26-,~,.t~g-2000 1900 3375 3325 0 500 51~ 455 3500 350( 1948 3325 332~ 0 0 0 0 720 575 0 0 550 128 3500 25.~ 346 3500 97..A u.~..20,".~) 1897 3375 3325 0 500 51~ 454 3500 350( 1942 3325 3325 0 0 0 0 720 575 0 0 550 125 3500 255 350 3500 28-A ug-2Ot~.~ ~898 3350 335{] 0 500 51C 454 3500 350( 1940 3350 335( 0 0 0 0 720 575 0 0 550 133 3500 25.' 342 3500 .. 9-.~ ..t g..,: 0~,01886 3350 335{] 0 500 51¢ 450 3500 350( 1925 3350 335( 0 0 0 0 720 575 0 0 550 135 3500 25.t 330 3500 30-A u~-2(.~X) 1891 3350 335{] 0 500 51¢ 451 3500 350( 1935 3350 335( 0 0 0 0 720 575 0 0 550 141 3500 25.' 328 3500 3 I..At~.20(.K~ 1872 3350 335{] 0 500 51¢ 445 3500 350( 1916 3350 335( .. 0 0 0 0 ,720, 575 0 0 550 143 3500 27( 324 3500 TOTAL 55,781 0 13,025 57,974 0 0 0 3,966 10,094 MAXIMUM 3,375 3,400 500 510 3,500 3,500 3,400 3,450 15 0 720 575 0 550 3,500 270~ 3,500 AVERAGE 1,799 3,349 3,346 0 500 509 420 3,500 3,50~ 1,870 3,354 3,37{] 0 10 0 0 711 563 0 0 550 128 3,500 252 326 3,497 #DAYS 31 0 31 ..... 31 ., 0, 0 ... 0 31 ..... 3,1 .... 09/18/2000 ~gust 13th - Wells temporarily ofllinc due to rapaiv~ to watedlood turbine. 1-23 shut in duc to annular coltnnunication problem. 4-23 has developed an annular communication problem. AOGCC notified on 12/12/99. Verbal approval to continue to inject received fi'om Mr. Wondzcll on 12/14/99. Sanuary-2002 Ol-Jan-2002 02-Jan-2002 03-./an-2002 04-$an-2002 05-$an-2002 06-Jan-2002 07-Jan-2002 08-Jan-2002 09-Jan-2002 ! 0-Jan-2002 I 1-Jan-2002 12-Jan-2002 13-Jan-2002 14-Jan-2002 15-$an-2002 16-$an-2002 17-$an-2002 18-Jan-2002 19-$an-2002 20-Jan-2002 21 -Jan-2002 22-Jan-2002 23-Jan-2002 24-Jan-2002 25-Jan-2002 26-$an-2002 27-.1'an-2002 28-Jan-2002 29-Jan-2002 30-Jan-2002 31 -Jan-2002 2025 3450 1977 3450 2010 3450 275 3450 2219 3400 2046 3400 2045 3450 2039 3450 1978 3450 1999 3425 2028 3425 2027 3425 1964 3425 1926 3400 1941 3400 1962 3400 1982 3400 1320 3400 1991 3425 1966 3425 1897 3425 1949 3425 1864 3425 1928 3425 1944 3425 1907 3425 1926 3425 1924 3425 1930 3425 1898 3425 1884 3450 C41-23 TOTAL MAXIMUM AVERAOE # DAYS 02/11/2002 C23-23 ACT ACT INJ INJ ANNU INI INJ ANNU 0 1800 20 I 0 1800 2O 0 1800 20 0 0 1800 20 0 0 570 570 0 570 570 0 570 570 0 570 570 0 570 570 0 570 570 0 570 570 0 570 570 0 570 57C 0 570 57C 0 570 57C 0 570 57£ 0 570 57{ 0 570 57{ 0 570 57{ 0 570 5~ 0 570 570 0 580 580 0 580 580 0 580 580 0 580 580 0 580 580 0 0 58O 580 0 0 580 580 0 58O 58C 0 580 58C 0 58,771 3,450 1,896 3,426 31 WATER INJECTION REPORT PLATFORM C C24-23 ACT INJ INJ ANNU 383 3450 345£ 330 3450 345C 0 3450 345C 0 3450 345{ 0 1150 !15{ 0 1150 115( 0 1150 115( 85 1150 115( 364 1150 1150 359 3300 3300 309 3300 3300 232 3300 3300 231 3300 3300 265 ' 2800 2800 351 2800 2800 350 3275 3250 352 3275 3250 C34-23 ACT INJ · INJ ANNU 1578 3100 305{ 1558 3100 305( 1597 3100 305( 212 · 3100 3050 1643 3050 3000 1585 3050 3000 1591 3100 3050 1597 3100 3050 1563 3100 3050 1574 3100 3050 1598 3100 3050 1595 3100 3050 1559 3100 3050 1546 3100 3025 1557 3100 3025 1564 3100 3025 1573 3100 3025 228 3275325~ 354 3275325~ 350 33003275 343 3300' 3275 348 32753275 341 3275327~ 349 32753275 351 3275327~ 347 3275327~ 351 3275327~ 349 3275327~ 349 3275327~ 346 3275327~ 395 34253492 C23-26 C41-26 C44-14RD ACT INJ INJ ANNU 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 0 0 0 0 0 0 0 ACT INJ INJ ANNU 0 700 60~ 0 70O 6~ 0 70O 60f 0 700 60( 0 800 692 0 800 692 0 800 625 0 800 692 0 800 625 0 800 625 0 800 625 0 800 625 0 800 625 0 800 625 0 800 625 0 0 800 625 0 0 795 625 ACT INJ INJ ANNU 0 0 550 0 0 550 0 0 550 0 0 550 958 1.800 550 0 0 575 0 0 550 0 0 550 0 0 550 380 1,300 550 0 0 55~ 0 0 550 350 1.300 55C 0 0 55C 360 1.200 55C 0 0 550 390 1.550 550 C24A-23 INJ INJ ANNU 0 0 600 0 0 600 0 0 600 0 0 600 0 0 600 0 0 600 0 0 600 0 0 600 0 0 600 0 0 6OO 0 0 6O0 0 0 6OO 0 0 60~ 0 0 60~ ,0 0 60~ 0 0 60~ 0 0 60~ C24A- 14 ACT INJ INJ ANNU 0 2750 0 2750 0 2750 0 2750 0 2O00 0 2OO0 0 1700 140 1600 306 1600 .268 3450 258 3450 252 3450 235 3450 229 3500 234 3500 284 3500 498 4470 0 1.800 580 · 0 732 502 0 986 3100 3025 1589 3100 3025 1577 3075 3025 1529 3075 3025 1566 3075 3025 1529 3075 302~ 1551 3075 302~ 1563 3075 3092 1533 3075 3092 1559 3075 3092 1556 3075 3025 1558 3075 3025 1537 3075 3025 1511 3100 3025 8,412 3.450 3,4501 271 2.934 2.929 26 46,634 3,100 3.O50 1,504 3,088 3,032 31 $1-23 shut in due to annular communication problem. }4-23 has developed an annular communication problem. AOGCC notified on 12/12/99. Verbal approvnl to continue to inject received from Mr. Wondzell on 12/14/99. .~4A-23 shut in for field study and evaluation per Dong Marshall. 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 0. 0 0 0 0 0 0 795 625 0 790 625 0 790 650 0 790 650 0 790 650 0 ' 790 65~ 0 790 65~ 0 790 65C 0 790 65C 0 790 65( 0 790 . 65C 0 790 65C 0 79O 65{ 0 850 65( ,. 0 850 65£ 0 785 631 0 0 0 550 0 0 550 356 1.800 550 0 0 550 0 0 550 330 1.500 550 0 0 550 309 1.400 550 0 0 575 0 0 550 210 1,300 550 0 0 560 324 1,300 570 0 0 550 3.967 1.800 575 128 466 553 10 0 0 60~ 0 0 60~ 0 0 60f 0 0 60( 0 0 0 0 0 0 60( 0 0 0 0 60O 0 0 6® 0 0 600 0 0 600 0 0 6OO 0 0 600 0 0 600 0 0 60O 0 456 4470 433 4550 419 4550 410 4550 413 4550 376 4550 368 4550 252 3100 31 4100 449 4100 306 4100 392 4100 370 4100 352 4400 7,731 4,550 249 3,498 24 ,, L December-2001 C23-23 ACT DATE & NOTES INJ INJ ANNU 01-Dec-200 ! 02-Dee-2001 03-Dec-200 ! 04-Dec-200 I 05-Dec-200 ! 2070 3425 2054 3425 2057 3425 2053 3425 2032 3425 06-Dec-2001 07-Dec-200 ! 08-Dec-2001 09-Dec-200 ! lO-Dec-2001 -Dec~2001 12-Dec-2001 3-Dec-2001 14-Dec-2001 - Dec- 200 I 16-Dec-2001 7-Dec-2001 -Dec-2001 19-Dec-2001 20-Dec-200 I -Dec-200 I 22-Dec-2001 23-Dec-2001 24-Dec-200 ! 25-Dec-2001 26-Dec-200 ! 27-Dec-200 ! 28-Dec-2001 29-Dec-2001 30-Dec-2001 l-Dec-2001 TOTAL MAXIMUM AVERAGE #DAYS 2067 3425 2051 3425 2055 3425 2044 3425 2042 3440' 2064 3440 1998 3450 266 3450 2323 3450 2103 3400 2092 3400 2120 3400 2097 3400 2091 3450 2067 3450 2072 3450 2046 3450 2073 3450 2059 3450 2027 3450 2076 3450 2049 3450 2058 3450 2038 3450 1922 3450 1837 3450 62,003 3,450 2,000 3,436 31 01/15/2002 E41-23 shut in due to annular communication problem. WATER INJECTION REPORT PLATFORM C C41-23 C24-23 C34-23 ACT ACT ACT INJ INJ ANNU: INJ INI ANNU INJ lNJ ANNU 0 565 565 370 3450 3450 1538 3100 305£ C23-26 ACT INJ INJ ANNU 0 0 0 565 565 0 565 565 0 565 565 0 565 565 0 0 565 565 0 0 565 565 0 0 565 565 0 0 565 565 0 0 550 57¢ 0 0 550 57{3 0 550 57£ 0 550 57C 0 550 57( 0 550 57C 0 550 57( 0 550 57( 0 550 57( 0 550 570 0 20 20 0 1300 20 0 1800 20 0 950 20 0 500 2(~ 0 650 20 0 0 1800 20 0 0 1800 20 0 1800 2{3 0 1800 2C 0 1800 2C 0 1800 2( ,800 57~ 858 35~ 368 3450 345~ 369 3450 345~ 369 3450 345{3 366 3450 345{3 373 345O 345{3 371 3450 345{3 371 3450 345£ 367 3450 345£ 371 3450 345( 376 3450' 345( 369 3450 345( 62 1300 135( 403 3500 350( 378 3450 345( 382 3450 3450 388 3450 3450 387 3450 3450 384 3450 3450 381 3450 3450 380 3450 3450 375 3450 345~ 382 3450 345~ 379 3450 345~ 370 345O 345{3 · 15333100 305( 1538 3100 305( 1537 3100 305( 1526 3100 305( 1549 3100 305( 1545 3100 305( 1550 3100 305( 1546 3100 3050 1548 3100 3050 1568 - 3100 3050 1543 3100 3050 203 1550 1525 1651 3100 3050 1590 3100 3050 1582 3100 3050 1601 3100 3050 1593 3100 305~ 1594 3100 305~ 1583 3100 305( 1586 3100. 305{3 1570 3100 305{ 1590 3100 305( 1581 3100 305( 1558 3100 305( 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 0 0 . 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 381 3450 345¢ 377 3450 345{3 378 3450 345( 374 3450 345( 355 3450 345( 362 3450 345f 11,3183,500 3,500I 365 3,382 3,384; 31 1596 3100 305( 1573 3100 3054 1576 3100 3050 1565 3100 3050 1483 3i00 3050 1437 3100 3050 47,033 3,100 3,050 1,517 3,050 3,601 31 .0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 E34-23 has developed an annular communication problem. AOGCC notified on 12/12/99. Verbal approval to continue to inject received from Mr. Wondzell on 12/14/99. C24A-23 shut in for field study and evaluation per Doug Marshall. C41-26 ACT INJ INJ ANNU 0 760 6OO 0 760 600 0 760 600 0 760 600 0 760 600 0 750 60~ 0 750 60~ 0 750 60~ 0 750 60~ 0 770 60~ 0 770 60{3 0 770 60~ 0 770 60~ 0 770 60( 0 770 60( 0 770 60( 0 770 60( ' 0 770 600 0 780 600 0 0 785 600 0 0 790 600 0 785 600 0 785 600 0 765 60~ 0 780 60~ 0 700 60~ 0 700 60~ o ~oo ~ 0 700 60( 0 700 60( 0 700 60( 0 79O 6O( 0 755 60~ 0 C44-14RD ACT INJ INJ ANNU 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 575 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 55C 0 0 55{3 0 0 55( 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 55O 0 0 550 0 0 575 0 0 550 0 0 550 0 0 5~ 0 0 570 0 0 575 0 0 553 0 C24A-23 ACT INJ INJ ANNU 0 0 0 0 6O( 0 0 6O{ 0 0 6O( 0 0 60( 0 0 59: 0 0 595i 0 0 595 0 0 595 0 0 6OO 0 0 6O0 0 0 6OO 0 0 595 0 0 595 0 0 595 0 0 595 0 0 595 0 0 595 0 0 592 0 0 59.~ 0 0 59.$ 0 0 59.~ 0 0 0 0 59.~ 0 0 595 0 0 595 0 0 595 0 0 595 0 0 595 0 0 595 0 0 595 0 0 6O0 0 0 596 0 C24A- 14 ACT INJ INJ ANNE 318 4600 326 4600 323 4600 322 4600 319 4600 319 4450 323 4450 317 4450 266 4500 370 4600 319 4550 0 3000 0 2600 349 4250 392 4500 372 4525 359 4525 248 4525 377 4550 351 4600 322 4600 305 4600 297 4600 310 4500 319 4500 324 4500 320 4500 312 4500 309 4500 304 4500 234 4500 9,326 4,600 301 4,415 29 WATER INJECTION REPORT PLATFORM C November-2001 , i C23-23 ACT DATE & NOTES INJ INJ ANNU 01-Nov-2001 02-Nov-2001 03-Nov-200 i 04-Nov-2001 05-Nov-2001 06-Nov-200 ! 07-Nov-200 ! 08-Nov-2001 09-Nov-2001 10-Nov-2001 I I-Nov-2001 12-Nov-2001 13-Nov-2001 14-Nov-2001 15-Nov-200 ! 16-Nov-2001 17-Nov-2001 18-Nov-2001 19-NOv-2001 20-Nov-2001 21-Now2001 22-Nov-2001 23-Nov-2001 24-Nov-2001 25-Nov-2001 26-Nov-200 ! 27-Nov-2001 28-Nov-2001 29-Nov-200 I 30-Nov-2001 TOTAL MAXIMUM AVERAGE #DAYS C41-23 ACT INI INJ ANNU 2004 3450 0 0 555 555! 2032 3450 0 0 555 555! 2019 3450 0 555 555 2022 3450 0 555 555 2029 3450 0 555 555 2014 3450 0 555 555 2010 3450 0 555 555 2028 3450 0 555 555 2012 3450 0 550 560 2035 3450 0 550 560 2079 3450 0 550 560 2075 3450 0 560 565 2114 3450 0 560 565 2093 3450 0 560 565 2104 3450 0 560 565 2117 3450 0 560 562 2098 3450 0 560 56~ 2096 3450 0 560 565 2102 3450 0 560 56~ 2100 3450 0 560 56~ 2081 3450 0 0 560 5651 2103 3450 0 0 565 565! 2115 3450 0 565 565 2129 3450 0 565 565 2142 3450 0 565 565 2116 3450 0 570 570 2034 3450 0 570 570 2096 3425 0 565 565 2069 3425 0 565 565 2067 3425 0 565 565 62,135 3,450 2,071 3,448 30 0 570 570 0 560 562 0 12/12/2001 C24-23 ACT INJ . IN./ ANNU 371 3450 3450 377 3450 3450 375 3450 345C 374 3450 345C 374 3450 345C 374 3450 345C 370 3450 345( 373 3450 345( 365 3450 345( 365 3450 345( 370 3450 345( 366 3450 345{ 372 3450 345o 365 3450 3450 366 3450 3450 37O 345O 345O 365 3450 3450 369 3450 345~ 367 3450 3450 367 3450 3450 362 3450 3450 366 3450 345~ 369 3450 345~ 369 3450 345C 370 3450 345C 367 345O 345C 364 3450' 345( 373 3450 345( 368 3450 345( 369 3450 345( C34-23 ACT INJ INS ANNU C23-26 ACT : INJ INJ ANNU ' C41-26 ACT INJ INI ANNU 11,072 3,450 3,45( 369 3,450 3,45( 30 1508 3100 306~ 1523 3100 1516 3100 306~ 1522 3100 306~ 1524 3100 306( 1516 3100 306( 1511 3100 306( 1526 3100 306( 1511 3100 305( 1510 3100 305( 1532 3100 305( 1527 3100 305( 1543 3100 3050 1528 3100 3050 1532 3100 3050 1541 3100 3050 1527 3100 3050 1533 3100 3050 1531 3100 3050 1523 3100 3050 1515 3100 305~ 1529 3100 306(] 1533 3100 306~ 1541 3100 306~ 1549 3100 306( 1532 3100 306( 1501 3100 306( 1547 3100 305( 1532 3100 305( 1537 3100 305( 45,800 3,100 3,06( 1,52~ 3,100 3,05.~ 3O 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 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 0 0 0 0 0 0 0 0 0 0 0 745 590 745 590 745 59~ 745 745 59~ 745 59C 745 5~ 745 59C 750 60( 750 60( 750 6~ 750 750 60( 750 6~ 750 600 750 600 750 600 750 600 750 600 750 600 750 600 76O 6OO 760 60~ 760 600 760 60(3 76O 60~ 76O 60~ 760 60~ 760 60~ 760 60~ 0 760 60~ 0 752 597 0 C44-14RD ACT · INJ INJ ANNU 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 575 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 55~ 0 0 55~ 0 0 55C o o 55C 0 0 55C 0 0 55C o o 55oi 0 0 550 0 0 550 0 0 550 0 O. 575 0 0 550 0 0 550 0 0 560 0 0 570 0 0 575 0 0 553 0 C41-23 shut in due to annular communication problem. C34-23 has dcveloped an annular cOmmunication problem. AOGCC notified on 12/12/99. Verbal approval to continue to inject received from Mr. Wondzell on 12/14/99. C24A-23 shut in for field study and evaluation per Dong Marshall. i C24A-23 ACT INJ INJ ANNL 0 0 6OO 0 0 6OO 0 0 6OO 0 0 6OO 0 0 6OO 0 0 60O 0 0 6OO 0 0 6OO 0 0 600 0 0 6OO 0 0 6OO 0 0 6O0 0 0 60~ 0 0 60~ 0 0 60~ 0 0 60C 0 0 60C 0 0 60C 0 0 60C 0 0 60C 0 0 60C 0 0 0 0 6O( o o 6oo 0 0 6O0 0 0 6OO 0 0 6OO 0 0 6OO 0 0 60O 0 0 60O 0 0 6OO 0 0 6OO 0 C24A-14 ACT INJ INJ ANNL 337 4500 335 4500 337 4500 343 4500 341 4500 334 4500 320 4500 313 4500 301 4450 307 4450 309 4450 305 4425 306 4425 292 4425 292 4400 301 4400 297 4400 308 4400 310 4400 310 4400 308 4450 310 4475 309 4475 310 4475 309 4475 301 4450 273 4450 339 4600 324 4600 321 4600 9,402 4,600 313 4,469 30 WATER INJECTION REPORT PLATFORM C October-2001 01-Oct-200 I 02-Oct-2001 03-Oct-2001 04-Oct-2001 05-Oct-2001 06-Oct-2001 07-Oct-2001 08-Oct-2001 09-Oct-200 I 10-Oct-2001 11 -Oct-2001 12-Oct-2001 I3-Oct-2001 14-Oct-2001 15-Oct-2001 16-Oct-2001 17-Oct-2001 18-Oct-2001 19-Oct-2001 20-Oct-2001 21 -Oct-200 1 22-Oct-2001 23-0ct-2001 24-Oct-2001 25-Oct-2001 26-Oct-2001 27-Oct-2001 28-Oct-2001 29-Oct-2001 30-Oct-2001 3 l-Oct-2001 TOTAL MAXIMUM AVERAGE # DAYS 11113/2001 C23-23 C41-23 C24-23 C34-23 C23-26 C41-26 C44-14RD ACT ACT INJ INJ ANNU INJ INJ ANNU 2077 3400 2084 3400 2082 3400 2071 3400 1290 3400 783 3400 2254 3400 2128 3400 2056 3400 1906 3400 0 34OO 762 3350 0 3350 2189 3350 2126 3400 2089 3400 1992 3400 1942 3400 1952 3400 1336 3400 2020 3400 2001 3400 2009 3400 2003 3400 2011 3400 2010 3400 1944 3400 2029 3400 1963 3450 1963 3450 2007 3450 55,079 3,450 !,777 3,400 29 0 550 56( 0 550 56( 0 560 56( 0 560 56( 0 560 56( 0 56O 56( 0 56O 56( 0 560 56( 0 56O 56( 0 560 56( 0 560 56( 0 550 56( 0 550 56( 0 550 56( 0 570 57( 0 570 57( 0 570 57( 0 570 57( 0 57O 57( 0 570 57( 0 570 57( 0 57O 57( 0 57O 57( 0 570 57( 0 570 57( 0 570 57( 0 570 57( 0 570 57( ACT INJ INJ ANNU 381 3450 3460 388 3450 3460 384 3450 346O 380 3450 3460 236 3450 346O 150 3450 3450 390 3450 3450 381 3450 3450 370 3450 3450 349 3450 3450 0 3450 3450 150 3450 3450 0 3450 3450 399 3450 3450 398 3450 3450 397 3450 3450 388 3450 3450 378 3450 3450 384 3450 3450 261 3450 3450 383 3450 3450 377 3450 3450 379 3450 3450 373 3450 3450 373 3450 3450 380 3450 3450 371 3450 3450 389 3450 3450 0 570 57( 374 3450 3450 0 570 570 372 3450 3450 0 555 555l 375 3450 3450 0 10,310 570 57( 3,450 3,460 0 563 56~ 333 3,450 3,452 0 29 ACT INJ INJ ANNU 1521 3150 315C 1545 3150 315C 1542 3150 3125 1530 3150 3125 955 3150 3125 54O 3100 305C 1579 3100 305C 1556 3100 305C 1521 3100 305C 1430 3100 305C 0 3100 305C 517 3000 300~ 0 '3000 300~ 1572 3000 300~ 1565 3100 305C 1556 3100 305C 1513 3100 305C 1490 3~00 305~ 1490 3t00 305C 1019 3:100 305C 1500 3100 305C 1530 3100 305C 1538 3100 305C 1530 3100 305C 1531 3100 3055 1534 3100 3055 1504 3100 3055 1568 3100 3055 1508 3100 306{ 1496 3100 306~ 1518 3100 306{ 41,198 3,150 3,15E 1,329 3,098 3,06~ 29 ACT INJ INJ ANNU 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 o o 0 o o o o o o o o o o o o o o o o o o o o o o o o o o o o o o o o o o o o o o o o o o o o 0 0 0 0 0 0 0 ACT INJ ' INJ ANNU 0 735 550 0 735 550 0 735 550 0 735 550 0 735 550 0 735 550 0 735 550 0 735 550 0 735 550 0 735 550 0 735 550 0 730 ' 550 0 730 550 0 730 55O 0 730 560 0 730 560 0 730 560 0 730 560 0 730 560 0 730 560 0 730 560 0 730 560 0 730 560 0 730 560 0 745 575 0 745 575 0 745 575 0 745 590 0 745 590 0 745 590 0 745 59(3 0 745 590 0 735 561 0 ACT INI INJ ANNU 0 0 55C 0 0 55C 0 0 55£ 0 0 55C 0 0 55C 0 0 575 0 0 55C 0 0 55C 0 0 55C 0 0 55C 0 0 55C 0 0 55C 0 0 55C 0 0 55C 0 0 55C 0 0 55£ 0 0 55£ 0 0 55C 0 0 55C 0 0 55C 0 0 55C 0 0 550 o o 55oi 0 0 5501 o o 55o 0 0 575 0 0 550 0 0 550 0 0 560 0 0 570 0 0 575 0 0 553 0 C24A-23 C24A- 14 ACT ACT ]~J INJ ANNI INJ INJ .ANNU 0 0 598 0 0 598 0 0 600 0 0 6O0 0 0 600 0 0 6OO 0 0 600 0 0 6OO 0 0 6O0 0 0 6O0 0 0 6O0 0 0 600 0 0 600 0 0 60O 0 0 595 0 0 595 0 0 595 0 0 595 0 0 595 0 0 595 0 0 595 0 0 595 0 0 595 0 0 595 0 0 6OO 0 0 60O 0 0 600 0 0 6OO 0 0 6OO 0 0 6OO 0 0 6OO 0 0 6O0 0 0 598 0 248 4450 C 145 4450 C 72 2575 12C 433 2575 12C 240 2575 12C 86 4300 lC 442 4300 lC 385 4300 lC 387 4450 lC 342 4450 lC 0 4450 lC 0 2400 14C 0 2400 14C 269 2000 23C 500 4450 439 4450 409 4450 353 4450 340 4450 228 4450 0 4450 446 4450 385 4450 370 4450 351 4500 340 4500 330 4500 345 4500 330 4500 333 4500 340 4500 8,888 4,500 23~ 287 4,054 3~ 27 241-23 shut in due to annular communication problem. 234-23 has developed an annular communication problem. AOGCC notified on 12/12/99. Verbal approval to continue to inject received from Mr. WonOzeH on 12/14/99. .~24A-23 shut in for field study and evaluation per Dong Marshall. WATER INJECTION REPORT PLATFORM C September-2001 C23-23 C41-23 C24-23 C34-23 C23-26 ACT ACT ACT ACT ACT INJ ]NJ ANNU ]NJ INJ ANI~U INJ INJ ANNU ]NJ ]NJ ANNU ]NJ ]NJ ANNU 01-Sep-2001 02-Sep-200 ! 03-Sep-2001 04-Sep-2001 05-Sep-2001 06-Sep-2001 07-Sep-2001 08-Sep-2001 09-Sep-2001 10-S~ )-2001 1 l-Se )-2001 12-Se )-2001 13-$e ~-2001 14-Se )-2001 15-Se )-2001 ! 6-Se )-2001 17-Se )-2001 18-Se )-2001 ! 9-Se )-2001 20-Se ~-2001 21 -Se )-2001 22-Se ~-2001 23-Se ~-2001 24-Se )-2001 25-Se )-2001 26-Se )-2001 27-Se ~-2001 28-Se ~-2001 29-Se ~-2001 30~Se ~-2001 TOTAL MAXIMUM AVERAGE #DAYS 10/15/2001 2179 3400 1627 3400 2262 3400 2199 3400 2223 3400 2228 3400 2247 3400 2253 3400 2260 3400 2264 3400 2264 3400 2264 3400 2251 3400 2284 3400 2256 3400 2251 3400 2252 3400 2181 3400 2146 3400 2171 3400 2163 3400 2184 3400 2189 3400 2177 3400 2191 3400 2187 3400 2196 3400 2172 3400 2146 3400 2138 3400 65,805 3,400 2,194 3,400 30 0 500 530 0 500 530 0 500 540 0 500 540 0 500 540 0 500 540 0 550 540 0 500 540 0 540 550 0 540 500 0 540 550 0 540 550 0 550 550 0 550 550 0 550 550 o sso ss° 0 550 550 0 550 550 0 550 550 0 550 550 0 550 550 0 550 550 0 550 550 0 550 550 0 550 550 0 550 550 0 550 56~ 0 550 56~ 0 550 56~ 0 550 56~ 0 550 560 0 537 546 0 374 34O0 345{ 292 3400 345£ 377 3400 345{ 366 3400 345{ 372 3400 345{ 372 3400 345{ 375 3400 345( 374 3475 345{ 374 3475 345( 371 3450 345( 371 3450 3475 370 3450 3475 370 3450 3425 376 3450 345( 373 3450 345{ 373 3450 3475 374 3450 3475 373 3450 3475 377 3450 3475 372 3450 345£ 37 ! 3450 345£ 372 3450 345( 372 3450 345( 372 3450 345£ 375 3450 345£ 372 3450 345£ 380 3450 346{ 376 3450 346{ 380 3450 346~ 376 3450 346~ 11,122 3,475 3,475 371 3,440 3,45~ 30 1567 2850 3100 1185 :~8:503.100 1582 28~o 31oo 1553 2~50 3100 1566 2800 3100 1560 2850 3100 1567 2500 31°° 1563 2850 31® 1562 2850 310( 1556 2850 310( 1549 2850 310( 1545 2850 310( 1537 2850 3100 1561 2850 3100! 1553 2850 3100 1551 2850 3100 1552 2850 3100 1534 2850 3100 1552 2850 3100 . 1531 2850 3!00 1528 2850 3100 1528 2850 3i00 1530 3100 3i00 1520 3100 3100 1528 3100 3TM 1518 3150 3100 1537 3150 3150 1530 3150 3150 1543 3150 3.150 1523 3150 3150 46311 3,150 3,150 1,534 2,922 3,107 30 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 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 0 0 0 0 0 0 0 0 0 0 0 C41-26 C44-14RD C24A-23 C24A- 14 ACT ACT ACT ACT INJ 1NJ ANNU ]NJ ]NJ ANNU ]NJ ]NJ ANNI~ ]NJ ]NJ ANN1 0 710 51£ 0 710 · 51( 0 710 55{ 0 710 55{ 0 710 55{ 0 710 55{ 0 710 55( 0 735 55{ 0 710 55( 0 710 55£ 0 710 55( 0 710 55( 0 715 55£ 0 770 55£ 0 770 55£ 0 770 55( 0 770 55{ 0 770 55( 0 770 55{ 0 770 55{ 0 770 55{ 0 770 55{ 0 770 55{ 0 770 55( 0 770 55( 0 770 55{ 0 735 55{ 0 735 55{ 0 735 55( 0 735 55( 0 770 55{ 0 740 54~ 0 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 575 0 0 550 0 0 55O 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 575 0 0 550 0 0 550 0 0 56O 0 0 570 0 0 575 0 0 553 0 0 75 58.~ 0 75 58.~ 0 0 585 0 0 585 0 0 58.~ 0 0 57( 0 0 58.~ 0 0 585 0 0 585 0 0 585 0 0 585 0 0 585 0 0 59f 0 0 59( 0 0 58( 0 0 58.~ 0 0. 58.~ 0 0 58f 0 0 58( 0 0 59f 0 0 59( 0 0 59( 0 0 59.~ 0 0 59.~ 0 0 59.~ 0 0 59~ 0 0 59~ 0 0 59~ 0 0 59~ 0 0 59~ 0 75 598 o 5 58~ 0 370 4500 339 4500 335 4500 337 4500 344 4450 346 4450 341 4450 337 4400 339 4400 · 341 4400 347 4400 343 4400 326 4400 335 4400 345 4400 360 4400 361 4400 337 4450 352 4450 339 4450 340 4450 348 4450 350 4450 342 4450 342 4450 338 4450 331 4450 335 4450 339 4450 342 4450 10,281 4,500 343 4,440 30 241,23shut in due to annular communication problem. 234-23 has developed an annular communication problem. AOGCC notified on 12/12/99. Verbal approval to continue to inject received from Mr. Wondzell on 12/14/99. 224A-23 shut in for field study and evaluation per Dong Marshall. .=, WATER INJECTION REPORT PLATFORM C August-2001 C23-23 C41-23 C24-23 C34-23 C23-26 C41-26 C44-14RD C24A-23 C24A- 14 NOTES : ACT ACT ACT ACT ACT ACT ACT ACT ACT ~ATE:&= i INJ INJ ANNU ][NJ INJ ANNU INJ INJ ANNU INJ INJ ANNU INJ' INJ ANNU INJ INJ ANNU INJ INJ ANNU ][NJ INJ ANNU INJ INJ' 01-Aug-2001 2275 3400 { 0 490 49( 387 3450 345~ 1569 2800 310~ 0 0 0 0 495 300 0 0 55{3 0 505 540 368 4500 02-Aug-2001 2276 3400 { 0 500 51{ 388 3450 345(} 1566 3500 310~ 0 0 0 0 650 490 0 0 55(3 0 505 540 246 4500 03-Aug-2001 2283 3425 { 0 500 51( 389 3450 345{] 1564 3500 310~ 0 0 0 0 650 500 0 0 55{3 0 490 545! 395 4550 04-Aug-2001 2277 3400 { 0 500 50( 388 3450 345{] 1559 3500 310~ 0 0 0 0 660 500 0 0 55{3 0 450 550 375 4550 05-Aug-2001 2268 3400 { 0 500 51( 386 3450 3450 1554 3500 310~ 0 0 0 0 660 500 0 0 55{3 0 425 550 372 4500 06-Aug-2001 2274 3400 { 0 500 51{ 389 3450 345{] 1556 3500 310(3 0 0 0 0 660 500 0 0 575 0 400 550 370 4500 07-Aug-2001 2269 3400 ( 0 500 51{ 391 3450 3450 1554 3500 3t0~ 0 0 0 0 660 500 0 0 55{3 0 375 550 370 4500 08-Aug-2001 2258 3400 { 0 500 51{ 391 3450 345{] 1555 2900 310~ 0 0 0 0 670 500 0 0 55{3 0 350 555: 359 4500 09-Aug-2001 2299 3400 f 0 500 51{ 390 3450 345{] 1556 2900 310~ 0 0 0 0 670 500 0 0 55{3 0 350 555~ 357 4500 10-Aug-2001 2324 3400 · { 0 500 51( 389 3450 345{] 1549 2900 310~ 0 0 0 0 670 500 0 0 55(] 0 350 555 334 4500 1 l-Aug-2001 2334 3400 { 0 500 51( 391 3450 345{] 1553 2900 310(3 0 0 0 0 670 500 0 0 55{3 0 325 560 362 4500 12-Aug-2001 2334 3400 { 0 500 51{ 390 3450 345{] 1552 2900 310~ 0 0 0 0 670 500 0 0 55{3 0 325 560 363 4500 13-Aug-2001 2352 3400 { 0 500 51{ 390 3450 345{] 1549 2900 310~ 0 0 0 0 670 500 0 0 55(3 0 325 560 362 4500 14-Aug-2001 2341 3400 { 0 500 51{ 390 3450 345{] 1545 2900 310(3 0 0 0 0 670 500 0 0 55{3 0 325 560 365 4500 15-Aug-2001 2332 3400 { 0 500 51{ 389 3450 345{] 1540 2900 310(3 0 0 0 0 670 500 0 0 55{3 0 325 560 361 4500 16-Aug-2001 1640 3400 { 0 500 51{ 286 3450 345{] 1132 2900 310~ 0 0 0 0 670 500 0 0 55{3 0 325 560 367 4500 17-Aug-2001 2300 3425. ( 0 500 47{ 385 3475 3475 1602 2900 310~ 0 0 0 0 690 500 0 0 55(3 0 250 530 359 4550 18-Aug-200 ! 2267 3425 ( 0 500 47( 38 ! 3475 3475 1582 2900 310~ 0 0 0 0 690 500 0 0 55(3 0 250 530 361 4550 19-Aug-2001 2269 3425 { 0 500 47( 381 3450 345{] 1576 2850 310(3 0 0 0 0 690 500 0 0 55(3 0 200 570 357 4525 20-Aug-2001 2240 3425 ( 0 500 47( 377 3450 345{] 1557 2850 310C 0 0 0 0 690 50(] 0 0 55(3 0 200 570 367 4525 21-Aug-2001 2244 3400 (~ 0 500 47( 380 3450 345{] 1556 2850 310( 0 0 0 0 690 50~ 0 0 55(3 0 175 570 351 4525 22-Aug-2001 1939 3400 0 0 500 47( 309. 3450 345{3 1389 2850 310( 0 0 0 0 690 50~ 0 0 55{3 0 175 570 273 4525 23-Aug-2001 2195 3400 (~ 0 500 470 322 3450 345{3 1560 2850 310( 0 0 0 0 690 50~ 0 0 55(3 0 175 570 0 4525 24-Aug-2001 2192 3400 0 0 500 470 322 3450 345{3 1558 2850 310 0 0 0 0 690 50~ 0 0 55C 0 175 570 356 4525 25-Aug-2001 2205 3400 0 0 500 470 324 3450 345{3 1562 2850 310( 0 0 0 0 690 50(3 0 0 55£ 0 125 580 383 4525 26-Aug-2001 2181 3400 0 0 500 470 329 3450 345{3 1546 2850 310( 0 0 '0 0 690 500 0 0 575 0 125 580 362 4525 27-Aug-2001 2210 3400 0 0 500 470 351 3450 345{3 1556 2850 310( 0 0 0 0 690 50(3 0 0 5501 0 125 580 362 4525 28-Aug-2001 2176 3400 0 0 500 470 348 3450 345(3 1538 2850 310( 0 0 0 0 690 50(] 0 0 5501 0 125 580 363 4525 29-Aug-2001 2189 3400. 0 0 500 470 351 3450 345(3 1533 2850 310( 0 0 0 0 690 50(] 0 0 56{ 0 75 582 364 4450 30-Aug-2001 2195 3400 0 0 500 530 351 3450 345(3 1533 2850 310( 0 0 0 .0 710 55{3 0 0 570 0 75 582 349 4450 31-Au~-2001 2133 3400 0 0 550 530 356 3400 345(3 1509 2850 310( 0 0 0 0 710 55{3 0 0 55(3 0 75 585 356 4450 TOTAL 69,071 0 11,391 47,610 0 0 0 0 10,689 MAXIMUM 3,425 0 550 530 3,475 3,475 3,500 3,10( 0 0 710 55{] 0 575 505 585 4,550 AVERAGE 2,228 3,404 0 0 501 494 367 3,450 3,452 1,536 2,992 3,100! 0 0 0 0 673 496 0 0 553 0 273 561 345 4,510 # DAYS 31 0 31 31 0 0 0 0 30 09112/2001 C41-23 shut in due to annular communication problem. C34-23 has developed an annular communication problem. AOGCC notified on 12/12/99. Verbal approval to continue to inject received from Mr. Wondzell on 12/14/99. C24A-23 shut in for field study and evaluation per Doug Marshall. .. . WATER INJECTION REPORT PLATFORM C July-2001 C23-23 C41-23 C24-23 C34-23 C23-26 C41-26 C44- ! 4RD C24A-23 C24A- 14 ~1'~!~ ~i):~; '~'' ~"*': ~ ~ ~' ~ :~ '" I~ ,~r[,~¢~ ., rf 1,,,,.,t.I~ :'' ,i~: ;: : ~:= i: ~;~.~,, i~r¢ ~?i~ ~,~,¢,; : INJ INJ ANNU INJ 1NJ ANNU INJ INJ ANNU INS INJ ANNU INJ INJ ANNU IN~ INJ ANNU IN~ IN~ ANNU INJ INJ ANNE INJ INS' _ 01-Jul-2001 2383 3400 8 0 450 44( 370 3450 3450 1551 2900 3108 0 0 ( 0 130 50 0 0 558 0 2150 39.' 360 4500 02-Jul-2001 2383 3400 8 0 450 44( 368 3450 3450 1570 2900 3108 0 0 ( 0 130 50 0 0 558 0 2000 41( 352 4500 03-Jul-2001 2391 3400 8 0 450 44( 367 3400 3400 1572 2800 3108 0 0 0 0 130 50 0 0 55~ 0 1850 42.' 348 4500 04-Jul-2001 2382 3400 ~ 0 450 440 368 3400 3400 1566 2800 3108 0 0 0 0 130 50 0 0 55~ 0 1750 430 355 4525 05-Jul-2001 2371 3400 8 0 470 470 370 3400 3400 1561 2800 3108 0 0 0 0 430 250 0 0 558 0 1750 480 347 4600 06-Jul-200 ! 2365 3400 {~ 0 480 470 365 3450 3450 1558 2800 3108 0 0 0 0 450 250 0 0 575 0 1600 450 339 4500 07-Jul-2001 2364 3400 ~ 0 480 470 365 3450 3450 1563 2800 310( 0 0 0 0 450 250 0 0 55~ 0 1600 455 343 4500 08-Jul-2001 2264 3400 ( 0 480 470 361 3450 3450 1512 2750 3108 0 0 0 0 470 258 0 0 55~ 0 1500 460 341 4550 09-Jul-2001 2373 3400 ¢ 0 490 475 376 3450 3450 1610 2800 310( 0 0 0 0 480 308 0 0 55~ 0 1350 465 337 4550 10-Jul-2001 2362 3400 '£ 0 490 475 373 3450 3450 1602 2850 310( 0 0 0 0 490 308 0 0 55C 0 1300 475 376 4550 ! l-Jul-2001 2291 3400 ¢ 0 490 480 319 3450 3450 1556 2800 310( 0 0 0 0 495 308 0 0 55( 0 ! 300 475 364 4500 12-Jul-2001 2319 3400 ( 0 490 480 343 3450 3450 1568 2800 310( 0 0 0 0 495 308 0 0 55C 0 1150 485 365 4500 13-Jul-2001 2347 3400 £ 0 490 480 345 3450 3450 1576 2800 310( 0 0 0 0 495 308 0 0 55£ 0 1125 490 340 4500 14-Jul-2001 2339 3400 ( 0 490 480 346 3450 3450 1568 2800 310( 0 0 0 0 495 308 0 0 550' 0 1075 495 335 4500 15-Jul-2001 2341 3400 ( 0 490 480 348 3450 3450 1570 2800 310( 0 0 0 0 495 308 0 0 550 0 1025 495 353 4500 16-Jul-2001 2352 3400 ( 0 490 480 354 3450 3458 1573 2800 310( 0 0 0 0 495 308 0 0 550 0 975 508 338 4500 17-Jul-2001 2369 3400 ( 0 490 480 362 3450 3458 1581 2800 310( 0 0 0 0 495 308 0 0 550 0 .950 505 389 4500 ! 8-$ul-2001 2352 3400 ( 0 490 480 363 3450 3450 1567 2800 310( 0 0 8 0 495 30( 0 0 550 0 950 505 369 4500 19-~ul-2001 2355 3400 ( 0 490 490 367 3475 3475 1575 2800 310( 0 0 8 0 495 30( 0 0 550 0 900 508 361 4550 20-~ul-2001 1987 3400 ( 0 490 49~ 338 3475 3475 1349 2800 3100 0 0 8 0 495 30( 0 0 550 0 900 508 367 4550 21-~ul-2001 2305 3400 0 0 490 49~ 390 3450 345~ 1588 2800 3100 0 0 8 0 495 30( 0 0 550 0 810 525 360 4550 22-Jul-2001 2291 3400 0 0 490 49~ 385 3450 345~ 1573 2850 3100 0 0 8 0 495 30( 0 0 550 0 760 52~ 362 4550 23-Jul-2001 2292 3400 0 0 490 49~ 385 3450 345~ 1569 2850 3100 0 0 {~ 0 495 30( 0 0 550 0 740 52~ 360 4550 24-Jul-2001 2297 3400 0 0 490 49~ 386 3450 345C 1566 2800 3100 0 0 ~ 0 495 30( 0 0 550 0 740 52~ 363 4550 25-~ul-2001 2343 3400 0 0 490 49( 392 3450 34.~ 1587 2800 3100 0 0 ~ 0 495 30( 0 0 550 0 740 52~ 377 4550 26-~ul-2001 2332 3400 0 0 490 49( 392 3450 345~ 1576 2850 3108 0 0 ( 0 495 30( 0 0 575 0 675 525 365 4500 27-Jul-2001 2322 3400 0 0 490 49( 390 3475 347-~ 1569 2850 3108 0 0 ( 0 495 30( 0 0 550 0 650 53¢ 367 4475 28-Jul-2001 · 2313 3400 0 0 490 49( 390 3475 347-~ 1559 2850 3100 0 0 ~ 0 495 30( 0 0 550 0 625 53( 372 4500 29-Jul-2001 2318 3400 0 0 490 49( 391 3475 347.~ 1567 2850 3108 0 0 ( 0 495 30( 0 0 560 0 575 53.~ 369 4500 30-Jul-2001 2124 ;3400 0 0 490 49( 372 3500 350( 1466 2800 3108 0 0 ( 0 495 30( 0 0 570 0 575 53.~ 354 4500 31-~ul-2001 ' 2294 3400 0 0 490 49( 390 3500 350( 1587 2800 3108 0 0 ( 0 495 30( 0 575 53.~ 375 4500 TOTAL 71,921 0 11,431 48,355 0 0 0 0 11,103 MAXIMUM' 3,400 0 490 49~ 3,500 3,50( 2,900 3,108 0 ~ 495 300 0 575 2,150 535 4,600 AVERAGE 2,320 3,400 0 0 483 477 369 3,452 3,453 !,560 2,816 3,100 0 0 ~ 0 441 261 0 0 55~ 0 1,118 49( 358 4,519 #DAYS 31 0 31 31 0 0 0 0 31 C41-23 shut in due to annular communication problem. C34-23 Ires developed an nnnulnr cemmuniention problem. AOC~C notified on 12/12/99. Ved~tl approval to continue to inject received from Mr. Wondzeil on 12/14/99. C24A-23 shut in for field study and evaluation per Doug Marshall 4., WATER INJECTION REPORT PLATFORM C June-2001 01-Sun-2001 02-Jun-2001 03-$un-2001 04-Jun-2001 05-Jun-2001 06-Jun-2001 07-Jun-2001 08-Jun-2001 09-Jun-2001 10-Jun-2001 11 -Jun-2001 12-Jun-2001 13-$un-2001 14-Jun-2001 15-Jun-2001 16-$un-2001 17-Jun-2001 18-Jun-2001 19-Jun-2001 204un.2001 21-$un-2001 22-Jun-2001 23-Iun-2001 24-Jun-2001 25-Jun-2001 26-Jun-2001 27-Jun-2001 28-$un-2001 29-Jun-2001 30-Jun-2001 TOTAL MAXIMUM AVERAGE # DAYS 07/10/2001 C23-23 ACT INJ ~NJ ANNU 345 3475 352 3475 343 3475 340 3500 333 3500 886 35OO 1596 3400 1574 3400 1912 3400 2029 3400 2363 3400 2570 3400 2872 3400 2746 3400 2708 3400 2727 3400 2749 3400 323 1850 718 3375 2633 3375 2569 3375 2502 3375 2451 3375 2476 3400 2399 3400 1972 2900 1789 3250 2099 325O 2439 3400 2407 3375 55,222 3,500 i,841 3,334 30 C41-23 ACT INJ INl ANNU 0 425 430 0 425 430 0 425 430 0 425 430 0 425 430 0 425 430 0 450 420 0 420 420 0 460 420 0 460 425 0 425 425 0 425 430 0 430 430 0 430 430 0 430 430 0 430 430 0 430 430 0 430 430 0 430 430 0 430 430 0 450 440 0 450 440 0 450 440 0 450 440 0 450 440 0 450 440 0 450 440 0 450 440 0 450 440 0 450 440 0 46O 44O 0 438 432 0 C24-23 ACT 1NJ INJ ANNU 394 3500 350( 395 3500 350( 395 3500 350( 393 3500 35O( 391 3500 350( 368 3500 350( 390 3500 350( 388 3500 350( 386 3500 350( 389 35OO 350( 384 35OO 350( 385 3500 350( 380 3500 350( 376 3500 350( 369 3500 350( 367 3500 350( 372 3500 350( 220 3475 347~ 0 3475 347~ 380 3450 345( 372 3450 345( 407 3400 340( 393 3400 340( 386 3400 340( C34-23 ACT INJ INJ ANNU 1923 3400 340(3 1943'3400 3400 1941 3400 3400 1932 34oo 34OO 1922 3400 3400 1466 3400 3400 1814 3200 3200 1703 3100 3100 1623 3100 3100 1601 '3150 3150 1588 3'100 3100 1590 3125 3125 1568 3125 3125 1572 3125 3125 1575 3125 3125 1586 3125 3125 1595 3125 3125 189 1400 1~ 755 3100 310(] 1586 3100 3160 1585 3100 3160 1562 3100 3160(] 1551 3100 3160(] 1573 3100 3160(] 1566 3100 310~ 385 2800 280(. 1302 2800 27513 277 3300 3300 1142 3000 3000 325 3300 3300 1361 2900 2960 372 3450 3454 1604 2~ 3160 371 3~ 3~ 1593 2~ 3160 1 10,454 46,311 3,500 3,50~ 3,400 3,400 348 3,373 3,373 1,544 3,080 3,092 29 30 C23-26 INJ INJ ~U 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 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 0 0 0 0 0 0 0 0 0 0 0 C41-26 C44.- 14RD C24A-23 C24A- 14 AG ACT AG ACT INJ INI ANNU INJ INJ ANNU INJ INJ ANN1 1NJ INJ ANNU 0 70 60 0 0 550 0 70 60 0 0 550 0 70 60 0 0 550 0 70 60 0 0 550 0 70 60 0 0 550 0 70 60 0 0 575 0 125 5( 0 0 550 0 I10 5( 0 0 550 0 80 5( 0 0 550 0 70 5~ 0 0 550 0 70 50 0 0 550 0 70 5( 0 0 550 0 70 5( 0 0 550 0 70 5( 0 0 550 0 70 5( 0 0 550 0 70 50 0 0 550 0 70 50 0 0 550 0 70 50 0 0 550 0 70 50 0 0 550 0 70 50 0 0 550 0 130 50 0 0 550 0 130 50 0 0 550 O, 130 50 0 0 550 0 130 50 0 0 550 0 130 50 0 0 550 0 130 50 0 0 575 0 130 50 0 0 550 0 130 50 0 0 550 0 130 50 0 0 560 0 130 50 0 0 570 0 0 130 i 0 575 0 94 0 0 553 0 0 251 4550 25 253 4550 25 249 4550 25 246 4600 30 256 4600 30 196 4600 30 246 4500 36 258 4600 30 262 4600 30 262 4550 35 246 4550 35 253 4550 35 219 4550 35 236 4550 35 228 4550 35 211 4550 35 205 4550 35 132 4200 9~ 62 3300 90 61 3300 9~ 72 3450 230 100 3400 235 117 3400 270 114 3450 260 138 3450 26~ 238 4200 90 189 4200 80 0 3050 25O 0 2600 338 0 2300 375 5,300 4,600 375 177 4,062 107 27 357 4575 358 4575 358 4575 366 46OO 371 4600 280 4600 378 4500 368 4600 352 4600 354 4600 350 460O 353 4600 318 ~ 350 46OO 338 ~ 317 4600 346 4~ 3~ 4275 122 3360 122 3300 151 3500 160 35OO 155 3500 178 3500 181 3500 381 4250 330 4300 419 4500 405 4550 364 44O0 9,186 4,600 306 4,280 30 241-23 shut in due to annular communication problem. 234-23 has developed an annular communication problem. AC)GCC notified on 12/12/99. Verbal approval Io continue to inject received from Mr. Wondzell on 12/14/99. WATER INJECTION REPORT PLAT-FORM C · May-2001 I -May-2001 02-May-200 ! 03-May-2001 04-May-2001 05-May-2001 06-May-200 ! 07-May-2001 08-May-2001 00-May-2001 10-May-2001 1 -May-2001 12-May-2001 3-May-2001 14-May-2001 15-May-2001 16-May-2001 17-May-2001 8-May-200 ! 19-May-2001 20-M. ay-2001 21-May-2001 22-May-2001 23-May-2001 24-May-200 1 25-May-2001 26-May-2001 27-May-2001 28-May-200 ! 29-May-2001 30-May-2001 1 -May-2001 TOTAL MAXIMUM AVERAGE # DAYS 06/13/2001 C23-23 ACT INJ INJ ANN{ 1380 3400 930 3400 738 3450 650 3400 596 3400 557 3400 534 3400 197 3400 0 2800 130 2600 7O4 34OO 529 3450 480 3450 448 3450 436 3450 298 3400 416 3400 381 3400 365 3400 356 3400 363 345O 367 3400 556 3400 449 3450 401 3450 383 3450 373 3450 363 3450 364 3450 366 3450 359 3475 14,469 3,475 467 3,378 30 ~:(~41~23 · ACT 1NJ INJ ANNU 0 450 450 0 450 450 .0 45o 450 !i 0 450 450 :0 450 450 0 450 450 0 450 450 ,0 450 450 0 450 450 ~ 0 480 440 0 485 440 0 450 435 0 475 435 0 475 435 0 450 435 0 435 435 0 435 435 0 435 435 0 435 435 0 435 435 0 425 430 ~ 435 435 0 ff 0 435 435 0 0 400 425 0 0 400 425 0 425 430 0 425 43O 0 425 430 0 425 430 0 425 430 0 425 430 0 50 485 450 2 0 441 438 0 ACT INJ INJ ANNU 377 3450 345~ 384 345O 345(3 377 3450 34513 378 3450 34513 378 3450 345~ 375 3450 345~ 380 3450 345(3 146 3450 345(3 0 1450 145(3 5 ! 1375 1375 410 3400 340~ 401 3450 34.~ 399 3450 345~ 392 3450 345(3 402 3450 34~ 266 3450 345(3 395 3450 34513 388 3450 34513 383 3450 34513 380 3450 34513 389 3450 345C 382 3450 345£ 383 3450 345C 395 3450 34513 391 3450 345{ 391 3450 345C 389 3450 345C 389 3450 345( 393 3450 345( 399 3450 345( 396 3500 350( 10,959 3,500 3,50~ 354 3,319 3,31~ 30 C34~23 ACT INJ 1NJ ANNU 1836 3350 335{ 1874 3350 335{ 1849 3350 335{ 1853 3350 335{ 1852 3350 335{ 1843 3350 335{ 1857 3350 335{ 713 3350 335{ 0 1500 150( 197 1475 147.~ 1977 3475 330( 1953 3500 332~ 1937 3500 335{ 1903 3500 335{ 1966 3500 335{ 1247 3300 330( 1940 3300 330( 1880 3300 330( 1835 3300 330( 1819 3300 330( 1842 3350 335{ 1799 3300 330( 1814 3300 33O( 1873 3350 3350 1854 3350 3350 1857 3350 3350 1843 3350 3350 1842 3350 3350 1857 3350 3350 1932 3350 3350 1945 3400 3400 52,789 3,500 3,400 1,703 3,244 3,218 30 C23-26 ACT INJ INJ ANNU 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 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 0 0 0 0 0 0 0 0 0 0 0 C41-26 ACT INJ INJ ANNU 0 50 513 0 50 5(3 0 50 5(3 0 50 5~ 0 50 5(3 0 50 513 0 50 513 0 50 513 0 50 5(3 0 50 5(3 0 50 5(3 0 50 5(3 0 50 5C 0 50 5(3 0 60 513 0 60 513 0 60 513 0 60 5(3 0 60 513 0 60 513 0 70 0 60 0 60 5(~ 0 70 6{ 0 70 6{ 0 70 6{ 0 70 6{ 0 70 6{ 0 70 0 70 0 70 0 70 6~ 0 58 53 0 C44-14RD ACT INJ INJ ANNU 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 575 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 575 0 0 550 0 0 550 0 0 560 0 0 570 0 0 56~ 0 0 575 0 0 553 0 C24A-23 ACT INJ INJ ANNU 167 4500 15 142 4500 15 193 4500 15 221 4550 15 161 4550 ! 80 4550 15 173 4550 190 4550 15 115 4300 313 178 4500 213 160 4500 213 171 4525 15 170 4500 15 162 4500 15 170 4500 22 92 3900 2~ 128 4500 213 136 4550 18 134 4600 18 105 4400 18 218 4525 25 127 4400 162 4400 174 4425 ! 80 4425 2-~ 176 4450 194 4500 2~ 218 4525 2.~ 238 4550 2.~ 219 4550 2~. 221 4550 2~ 5,275 4,600 313 170 4,478 213 31 C24A- 14 ACT INJ INJ. ANNU 370 4575 249 4575 399 4550 399 4575 332 4575 368 4575 371 4575 401 4575 209 4350 379 4600 398 4600 402 460O 395 4575 362 4575 218 4000 424 4500 400 4450 377 4600 337 4450 363 4575 368 4450 354 4450 352 4500 353 4500 369 4500 385 4550 363 4575 361 4600 359 4600 365 4575 11,186 4,600 361 4,527 31 C41-23 shut in due to annular communication problem. C34-23 has developed an annular communication problem. AOGCC notified on 12/12/99. Verbal approvnl to continue to inject received from Mr. Wondzell on 12/14/99. April-2001 01 -Apr-2001 02-Apr-2001 03-Apr-2001 04-Apr-2001 05-Apr-2001 06-Apr-2001 07-Apr-2001 WATER INJECTION REPORT PLATFORM C C41-23 C24-23 C34-23 ACT ACT ACT li~J INJ ANN~ INI INJ ANNU INJ INJ ANNU 0 500 490 0 500 490 0 500 490 0 500 490 0 500 490 0 500 490 374 3450 345~ 392 3450 345(] 396 3450 345(] 390 3450 345(] 388 3450 345(] 387 3450 345C 384 3450 345C 1765 3350 335( 1895 3350 335( 1891 3350 3350 1881 3350 3350 1856 3350 3350 1836 3350 3350 1825 3350 3350 C23-23 ACT INJ INJ ANNU 0 500 490 C23-26 ACT INJ INJ ANNU 0 0 0 0 0 0 0 0 0 0 0 0 0 0 C41-26 ACT INJ INJ ANNU 0 760 60C 0 76O 60( 0 770 60( 0 770 60( 0 770 60( 0 770 60( 0 770 60( 0 770 60( 0 770 60( 0 770 60( 0 770 60( 0 790 62~ 0 790 62~ 0 790 62~ 0 775 62~ 0 770 62~ 0 770 6251 0 770 6251 0 770 625 0 770 625 0 770 625 0 770 625 0 -770 625 0 77O 625 0 770 625 0 775 625 0 775 625 0 775 625 0 775 625 0 775 625 C44-14RD ACT 1NJ INJ ANNU 0 0 55O 0 0 550 0 0 550 0 0 550 0 0 550 1,011 1,300 575 0 0 55O 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 55(] 0 0 550 0 0 550 0 0 55(] 0 0 55(] 0 0 55(] 400 1,300 575 0 0 55(] 548 1,375 55(] 790 !,400 56(] 954 1,375 57(] C24A-23 ACT INJ 256 4500 269 4500 259 4550 210 4550 216 4550 224 4550 242 4550 211 4550 203 4550 121 4550 264 4450 245 4500 237 4550 213 4550 179 4500 185 4500 186 4500 165 4525 157 4525 149 4525 139 4525 133 4525 129 4525 122 4450 126 4450 163 4450 174 4525 162 4500 156 4500 169 4500 08-Apr-2001 09-Apr-2001 10-Apr-2001, ! l-Apr-2001 ! 2- Apr-2001 i 3-Apr-2001 14-Apr-2001 15-Apr-2001 16-Apr-2001 17-Apr-2001 ! 8-Apr-2001 19-Apr-200i 20-Apr-2001 21 -Apr-2001 22-Apr-200 ! 23-Apr-2001 24-Apr-2001 25-Apr-2001 26-Apr-2001 27-Apr-200 I 2g-Apr-2001 29-Apr-2001 30-Apr-2001 TOTAL MAXIMUM AVERAGE # DAYS 05/15/2001 0 880 160( o 88o i6o< 0 94O 160( 0 940 160( 0 480 160( 0 350 160( 0 290 1851 0 290 185 0 290 185 0 290 185 0 290 185 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 0 0 0 0 0 0 0 0 0 172 2800 0 500 490 0 500 490 0 500 490 0 500 490 0 490 475 0 490 475 0 490 470 0 490 47(] 0 490 47(] 0 490 47(] 0 490 47(] 0 490 47(] 0 490 47(] 0 490 47(] 0 490 47(] 0 490 47(] 0 490 47(] 0 490 47(] 0 450 45~ 0 450 45(] 0 450 45~ 0 450 45~ 0 450 45~ 385. 3450 345~ 386 3450 345(] 384 3450 345C 382 3450 345~ 388 3500 345~ 387 3500 345~ 39 ! 3500 345~ 394 3500 345C 396 3500 345C 393 3500 345£ 395 3500 3475 394 3500 3475 392 3500 3475 390 3500 3475 389 3500 347.~ 385 3500 347.~ 383 3500 347.~ 379 3500 347.~ 382 3450 345{ 378 3450 3450 379 3450 3450 390 3450 3450 385 3450 3450 1819 3350 3350 1806 3350 3350 1801 3350 3350 1786 3300 3300 1808 3500 3350 1808 3500 3350 1833 3500 3375 1842 3500 3375 1847 3500 3350 1844 3500 3375 1855 3500 34OO 1855 35O0 3400 ! 842 3500 3400 1832 3500 3400 1828 3500 3400 1810 3500 3400 1800 3500 3400 1774 3500 3400 1792 3350 335~ 1770 3350 335(] 1768 3350 335(] 1855 3350 335~ 1839 3350 335(] 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 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 172 2,800 1,6O0 6 291 351 1 0 500 49(] 0 487 474 0 11,618 3,500 3,475 387 3,473 3,457 30 54,763 3,500 3,400 1,825 3,418 3,364 30 0 0 0 0 0 0 790 625 0 0 772 616 0 3,703 1,400 575 123 225 553 5 5,664 4,550 189 4,516 30 .~41-23 shut in due to annular communication problem. :34-23 has developed nn annular communication problem. AOGCC notified on 12/12/99. Verbal approval to continue to inject received from Mr. Wondzell on 12/14/99. ~3-23 shut in for repairs from 4/1/01 Ihru 4/29/01. Returned to injection on 4/30/01 ~ ! :30 p.m. C24A- 14 ACT INJ INJ ANNI 338 4550 346 4550 370 4600 368 4600 370 4600 373 4600 367 4600 365 4600 380 4600 163 4600' 384 4500 379 4550 386 4600 377 4600 367 4600 374 4600 374 4600 0 368 4625 0 370 4625 0 366 4625 0 381 4625 392 4625 372 4625 238 3150 408 3150 381 4500 383 4600 381 4575 383 4575 368 4575 10,872 0 4,625 0 362 4,494 WATER IN~ECTION REPORT PLATFORM C March-2001 C23-23 C4 !-23 C24-23 . C34-23 C23-26 C4 !-26 C44-14RD C24A-23 C24A- 14 :::::::::::::::::::::::::::::::::::::::::::::::::: ACT ACT ACT ACT ACT ACT ACT ACT ACT 01-Mar-2001 0 1700 1600 0 500 52( 424 3500 35® 2010 3400 3400 0 0 0 0 650 500 0 0 550 262 4500 0 390" 4550 02-Mar-2001 0 1700 1600 0 500 52( 412 3500 3500 1940 3400 3400 0 0 0 0 650 50C 0 0 550 258 4500 C 387 4550 03-Mar-2001 0 1500 1500 0 500 520 405 3500 3500 1902 3400 3400 0 0 0 0 650 500 0 0 550 258 4500 0 380 4550 04-Mar-2001 0 1500 1500 0 500 520 402 3500 3500 1885 3400 3400 0 0 0 0 650 50¢ 0 0 550 256 4500 ¢ 378 4550 05-Mar-2001 0 1500 1500 0 500 520 403 3500 3500 1870 . 3400 3400 0 0 0 0 700 55~ 0 0 550 242 4500 ¢ 382 4550 06oMar2001 0 1450 1450 0 500 520 409 3500 3500 1891 3400 3400 0 0 0 0 700 55¢ 0 0 550 230 4500 C 381 4550 07-Mar-2001 0 1450 1450 0 500 520 402 3500 350~ 1856 3400 3400 0 0 0 0 700 55¢ 0 0 550 209 4500 ¢ 377 4550 08-Mar-2001 0 1700 1600 0 500 520 424 3500 3500 2010 3400 3400 0 0 ' 0 0 650 50( 0 0 550 262 4500 ¢ 390 4550 09-Mar-2001 0 1500 140~ 0 500 520 402 3450 345¢ 1852 3100 3350 0 0 ~ 0 700 55( 0 0 550 201 4500 ( 347 4550 10-Mar-2001 0 1500 '140¢ 0 500 520 402 3450 345~ 1843 3100 335~ 0 0 - ¢ 0 700 55( 0 0 550 265 4500 ( 384 4550 II-Ma~2001 0 1450 135~ 0 500 520 .403 3450 345¢ 1847 3100 3350 . 0 0 ° ¢ 0 700 55( 0 0 550 248 4500 ( 389 4550 12-Mar-2001 0 1400 135C 0 500 520 405 3450 345¢ 1855 3100 3350 0 0 C 0 700 55( 0 0 550 207 4500 ( 388 4600 13-Mar-2001 0 1400 135C 0 500 520 408 3400 335~ 1865 3100 3350 0 0 ~ 0 700 55( 0 0 550 236 4550 ( 398 4600 14-Mar-2001 0 1400 135f 0 500 520 405 3400 335( 1863 3100 335¢ 0 0 ( 0 700 55( 0 0 550 286 4550 ( 386 4600 15-Mar~2001 0 1400 100f 0 500 520 397 3400 345( 1825 3100 3342 0 0 ( 0 740 60( 0 0 550 224 4500 376 4550 16-Mar-2001 0 580 80( 0 500 505 401 3500 345f 1845 3500 335¢ 0 0 ( 0 750 60( 0 0 550 203 4550 ( 368 4500 · 17-Mar-2001 0 360 90( 0 500 500 404 3500 347~ 1861 3500 337~ 0 0 ( 0 750 60( 0 0 550 198 4450 ~ 361 4525 18-Mar-2001 0 295 92~ 0 500 505 399 3500 345( 1836 3500 335¢ 0 0 ( 0 750. 60( 0 0 550 203 4425~ 364 4500 19-Mar-2001 0 295 102~ 0 500 50( · 394 3500 342! 1824 3500 332~ 0 0 ( 0 , 750 600 0 0 550 256 4425 0 368 4500 20-Mar-2001 0 350 !17 0 500 50C 398 3500 .345( 18~6 3500 335( 0 0 ( 0 750 600 0 0 550 274 4400 0 368 4500 21-Mar-2001 0 480 132~ 0 500 50~ 399 3500 ~ 345( 1858 3500 335( 0 0 ( 0 750 600 0 0 550 242 4400 0 387 4500 22-Mar-2001' 0 480 132~ 0 500 50( 393 3500 345( 1830 3500 335( 0 0 ( 0 750 600 0 0 550 240 4400 0 386 4500 23-Mar-2001 0 620 1500 0 500 50( 391 3500 3450 1830 · 3500 335( 0 0 0 0 750 600 0 0 550 272 4400 0 380 4500 24-Mar-2001 0 700 1550 0 500 50( 391 3500 3450 1853 3500 335( 0 0 0 0 750 600 0 0 550 269 4400 0 390 4500 25-Mar-2001 0 615 1550 0 500 50( 391 3500 3450 1856 3500 335( 0 0 0 0 750 600 0 0 550 220 4550 0 344 4575 26-Mar-2001 0 615 1550 0 500 50( 391 3500 3450 1869 3500 3350 0 0 0 0 750 600 0 0 550 273 4550 0 412 4575 27-Mar-2001 0 615 1550 0 500 50( 394. 3500 3450 1881 3500 3350 0 0 0 0 750 600 0 0 550 271 4550 0 392 4575 28-Mar-2001 0 615 1550 0 500 500 394 3500 3450 1872 3500 3350 0 0 0 0 750 600 0 0 550 265 4550 ~ 332 4575 29-Mar-2001 0 615 1550 0 500 500 392 3500 3450 1884 3500 3350 0 0 0 0 750 600 0 0 550 270 4550 0 389 4575 30-Mar-2001 0 880 1600 0 500 490 392 3450 3450 1843 3350 3350 0 0 0 0 760 60~ 0 0 550 272 4500 0 385 4550 31-Mar-200.! .... 0 880 1600 0 500 490 393 3450 3450 1837 3350 3350 0 0 0 0 760 60~ 0 0 550 265 4500 ~ 375 4550 TOTAL 0 0 12,420 57,939 0 0' 0 7,637 11,734 MAXIMUM 1,700 1,600 500 520 3,500 3,500 3,500 3,400 0 0 760 600 0 550 4,550 0 4,600 AVERAOE 0 1,018 1,383 0 500 509 401 3,481 3,456 1,869 3,374 3,363 0 0 0 0 720 569 0 0 550 246 4,490 0 379 4,545 , # DAYS 0 0 31 31 0 0 0 31 31 04/12/2001 241-23 shut in due to annular communication problem. 234-23 has developed an annu~r communication problem. AOGCC notified on 12/12/99. Verbal approval to continue to inject received f~om Mr. Wondzell on 12/14/99. 223-23 shut in for upcoming drilling operation in April. January-99 C23-23 C41-23 C24-23 C34-23 C23-26 C41-26 C44-14RD C24A-23 :!!!!i:i!i!iiiii!iii!i!iiiiii~!i!iiii~i~CT ACT ACT ACT ACT ACT ACT ~CT iiii~i~ii{ililil tNJ tNJ ANNU tN~ tN~ ANNU tNJ INJ ANNU 1NJ INJ ANNU tN~ INJ ANNU INJ IN~ ANNU INJ tNJ ANNU INJ 1NJ ANNU 01-Jan-99 1357 32'00 3125 978 700 660 386 3500 3500 1841 3500 0 0 0 0 0 0 400: 0 0 550 0 1200 75 02-Jan-99 1340 3200 3125 967 700 660 383 3500 3500 1811 3500 0 0 0 0 0 0 400 0 0 550 0 1200 75 03-Jan-99 300 3200 3125 368 700 660 85 3500 3500 487 3500 0 0 0 0 0 0 400i 0 0 550 0 1200 75 04-Jan-99 0 3200 3125 0 700 660 0 3500 3500 0 3500 0 0 0 0 0 0 400 0 0 550 0 1200 75 05-Jan-99 0 2000 2000 0 575 575 0 1600 1600 0 1275 0 0 0 0 0 0 400 0 0 550 0 1050 80: 06-Jan-99 0 2000 2000 0 575 575 0 1600 1600 0 1275 0 0 0 0 0 0 400 0 0 550 0 1025 80 07-Jan-99 1220 3100 3000 677 700 630 347 3500 3500 1533 3500 0 0 0 0 0 0 400 0 0 550 0 3500 08-Jan-99 1431 3100 3000 915 700 630 411 3500 3500 1888 3500 0 0 0 0 0 0 400 0 0 550 0 3500 0i 09-Jan-99 1352 3100 3000 907 700 630 339 3500 3500 1845 3500 0 0 0 0 0 0 400 0 0 550 0 3500 0I 10-Jan-99 1300 3150 3050 896 700 640 407 3500 3500 1799 3500 0 0 0 0 0 0 400 0 0 550 0 3500 0i fl-Jan-99 1351 3150 3050 511 700 640 386 3500 3500 1825 3500 0 0 0 0 0 0 400] 0 0 550 0 1800 0 '-~r~Jan-99 1332 3150 3050 744 700 640 438 3500 3500 1826 3500 0 0 0 0 0 0 400i 0 0 550 0 1050 tlJan-99 1327 3200 3100 755 700 640 426 3500 3500 1824 3500 0 0 0 0 0 0 400 0 0 550 0 3500 e4'-Jan-99 1325 3200 3100 751 700 640i 80 3500 3500 1832 3500 0 0 0 0 0 0 400 0 0 550 0 3500 15-Jan-99 1334 3200 3100 752 700 640 0 3500 3500 1856 3500 0 0 0 0 0 0 400 0 0 550 0 3500 16-Jan-99 1334 3200 3100 754 700 640 45 3500 3500 1856 3500 0 0 0 0 0 0 400 0 0 550 0 2050 17-Jan-99 1337 3200 3100 754 700 640 417 3500 3500 1858 3500 0 0 0 0 0 0 400 0 0 550 0 1750 18-Jan-99 1329 3200 3100 753 700 640 432 3500 3500 1856 3500 0 0 0 0 0 0 400 0 0 550 0 1750 19-Jan-99 1329 3200 3100 756 700 640 415 3500 3500 1863 3500 0 0 0 0 0 0 400 0 0 550 0 1300 20-Jan-99 1339 3200 3100 755 700 640 419 3500 3500 1886 3500 0 0 0 0 0 0 400 0 0 550 408 3500 0 21-Jan-99 1341 3200 3100 757 700 640 421 3500 3500 1903 3500 0 0 0 0 0 0 400 0 0 550 156 3500 22-Jan-99 1348 3200 3150 759 700 630i 419 3500 3500 1897 3500 0 0 0 0 0 0 400 0 0 550 57 3500 0 23-Jan-99 279 2200 2400 254 650 590 92 1700 1725 409 1000 0 0 0 0 0 0 400 0 0 550 0 1825 35 24-Jano99 0 2150 2400 0 650 590 0 1700 1725 0 1000 0 0 0 0 0 0 400 0 0 550 0 1500 35 25-Jan-99 0 2150 2050 0 650 590 0 1600 1600 0 I000 0 0 0 0 0 0 400 0 0 550 0 1500 85 26-Jan-99 829 3200 2050 392 700 590 245 3500 1600 1222 3500 0 0 0 0 0 0 400 0 0 550 0 1100 85 27-Jan-99 1345 3200 3110 732 700 630 405 3500 3500 2125 3500 0 0 0 0 0 0 400 0 0 550 206 3500 0 28-Jan-99 1319 3200 3110 754 700 630 404 3500 3500 2141 3500 0 0 0 0 0 0 40( 0 0 550 300 3500 0 29-Jan-99 1296 3200 3110 758 700 630 403 3500 3500 2121 3500 0 0 0 0 0 0 400 0 0 550 122 3500 0 30-Jan-99 1281 3200 3110 750 700 630] 400 3500 3500 2117 3500 0 0 0 0 0 0 400 0 0 550 25 3500 0 31-Jan-99 1241 3200 3110 744 700 630: 394 3500 3500 2071 3500 0 0 0 0 0 0 400 0 0 550 0 1625 0 TOTAL 31,916 18,893 8,599 45,692 0 0 0 1,274 MAXIMUM 3,200 3,150 700 660i 3,500 3,500 3,500 0 0 0 0 400 0 550 3,500 85 "~LRAGE 1,030 3,008 2,908 609 687 629 277 3,200 3,140 1,474 3,115 0 0 0 0 0 0 400 0 0 550 41 2,359 23 ~ ~AYS 26 26 25 26 0 0 0 7 02/10/99 All ~jecto~ down January 4, 5 & 6 due to water'flood turb~e annu~ maintenance. All i~ectors down January 24 & 25 due to watefflood turb~e annual maintenance. ..... WATER INJECTION REPORT PLATFORM C December-90 C23-23 C41-23 C24-23 C34-23 C23-26 C4 !-26 C44-14RD C24A-23 01-Dec-99 1389 3175 3100 0 575 650 383 3460 3475 1941 3525 0 0 50 C 0 645 45¢ 0 0 550 108 3460 02-De¢-90 1394 3175 3100 0 575 650 390 3460 3475 1945 3525 0 0 50 C 0 645 45¢ 0 0 550 150 3460 03-De0-90 1394 3175 3100 0 575 650 382 3500 3475 1941 3500 0 0 50 C 0 645 ~5C 0 0 550 325 4500 04-De¢-99 1392 3175 3100 0 575 650 382 3500 3475 1931 3500 0 0 50 C 0 645 45C 0 0 550 376 4500 05-De0-99 1391 3175 3100 0 575 650 380 3500 3475 1928 3500 0 0 50 ~ 0. 645 · 45C 0 0 550 335 4500 06-De¢-90 1389 3175 3100 0 575 650 379 3500 3475 1931 3500 0 0 50 ~ 0 645 45~ 0 0 550 317 4500 07-Dec-99 1388 3175 3100 0 575 650 378 3500 3475 1928 3500 0 0 50 0 0 645 45~ 0 0 550 314 4500 08-De¢-99 1332 3175 3100 0 575 650 373 3500 3475 1844 3500 0 0 50 ' 0 0 645 450 0 0 550 309 4500 09-Dee-99 1386 3175 3100 0 575 650 383 3500 3475 1921 3500 0 0 50 0 0 645 450 0 0 550 276 4500 10-De¢-90 1388 3200 3050 0 525 650 386 3500 3500 ' 1933 3500 0 0 0 0 . 645 450 0 0 550 89 3500 II-Dec-90 1390 3200 3050 0 525 650 386 3500 3500 1937 · 35.00 205 0 0 0 0 645 450 0 0 550 343 3500 12-De0-99 1391 3200 3050 0 580 650 386 3500 3500 1943 3500 3400 0 0 O 0 650 450 0 0 550 297 4400 13-Dec-99 1395 3200 3050 .0. 580 650 388 3500. 3500 1953 3500 3400 0 0 0 0 '650 450 0 0 550 285 4450 14-Dec-90 1386 3200 305C 0 580 650 385 3500 3500 1938 3500 3400 0 0 0 0 650 450 0 0 550 277 4450 15-De0-99 1379 3200 305¢ 0 580 650 382 3500 3500 1704 3500 3400 0 0 . 0. 0 650 450 0 0 550 103 4450 16-Dee-90 1382 3200 305C 0 580 650 379 3500 3500 1683 3500 340( 0 0 0 0 650 450 0 0 550' 0 4450 17-Dec-90 1372 3200 305C 0 580 650 374 3500 3500 1738 3500 340( 0 0 ' 0 0 650 450 0 0 550i 0 4450 18-Dee-90 1364 3200 305C 0 580 65( 371 3500 350( 1738 3500 340( 0 0 0 0. 650 450 0 0 550 140 4450 19-De0-99 .1371 3200 305C 0 580 65( 375 3500 350( 1757 3500 340C 0 0 0 0 650 450 0 0 550 109 4450 20-Dee=99 1391 3200 305C 0 580 65( 380 3500 350( 1814 3500 340( 0 0 0 . 0' 650 450 0 0 550 146 4450 21-Dee-90 1378 3200 305C 0 580 65C 379 3500 350C 1807 · 3500 340( 0 0 0 0 650 450 0 0 550 151 4450 22-Dee-99 1396 3200 305C 0 580 65C 383 3500 350( 1837 3500' 340( 0 0 0 0 650 450 0 0 550 160 4450 23-De~-90 1383 3160 3050 0 575 65C 379 3450 345C 1839 3525 340( 0 50 0 0 650 450 0 0 550 162 3475 24-Dec-99 1404 3170 3050 0 575 65C 385 3475 3480 1882 3550 340C 0 50 0 0 .640 450 0 0 550 168 3490 25-Dec-90 1391 3160 3050 0 580 65C . 383 3450 3470 1869 3525 340( 0 50 0 0 650 450 0 0 550 167 ' 3475 26-[~,c-90 140~ 3195 3075 0 580 65C 394 3500 350C 1~07 3550 3420 0 50 0 O 650 ' 450 0 0 550 171 3500 27-De=-99 1425 3190 306C 0 575 65C 395 3500 350C 1923 3555 342~ 0 50 0 0 650 450 0 0 550 173 3500 28-Dec-90 1419 3190 3075 0 580 65C 394 3500 350( 1911 3560 3420 0 50 0 0 650 450 0 0 550 171 3500 29-Dec-90 1413 3190 3075 0 580 65C 390 3500 350C 1905 3560 3420 0 50 0 0 650 450 0 0 550 171 3500 30-Dec-90 1408 3190 3075 0 580 65¢ 387 3500 350C 1898 3560 3420 0 50 0 0 650 450 0 0 550 170 3500 . 31-Dec-90 1423 3190 3075 0 580 65¢ 392 3500 350C 1930 3560 3420 0 50 0 .0 650 450 0 0 550 174 3500 TOTAL 43,1 ! 3 0 ! 1,883 58,156 0 0 0 6,137 MAXIMUM 3,200 3,100 5~0 650 3,500 3,500 3,560 3,425 50 0 650 450 0 550 4,500 AVERAGE i~91 3,187 3,069 0 575 650 383 3,493 3,490 i,876 3,516 2,205 0 29' 0 0 648 450 0 0 550 198. 4,057 , #DAYS 31 '0 31 31 0 0 ..0 29 A1 I11//~d~ ll-23 shut in due to annular oommunication problem. J4-23 has developed an annular communica6on problem. AOGC~ notified on 12/12/99. Vabal approval to continue to inject received from Mr. Wondzell on 12/14/99. WATER INJECTION REPORT PLATFORM C s November-99 C23-23 C41-23 C24-23 C34-23 C23-26 C41-26 C44-14RD C24A-23 :i:i:i:i:i:'i':i:i:i:!:~:i:i:i:i:i~i~ili~i~il A~T ACT ACT ACT ACT ACT ACT ~ACT 01-Nov-99 1316 35~0 3110 0 750 650 394 3500 . 3500 1940 3550 0 0 50 0 0 635 45¢ 0 0 550 244 3500 140 02-Nov-99 1316 3500 3110 0 750 650 398 3500 3500 1962 3550 0 0 50 0 0 635 45C 0 0 550 247 3500 140 03-Nov-99 1313 3500 3110 0 750 650 395 3500 3500 1965 3550 0 0 50 0 0 635 '45£ 0 0 550 230 3500 125 04-Nov-99 1365 3500 3110 0 750 650 396 3500 3500 1978 3550 0 0 50 0 0 635 45£ 0 0 550 120 3500 125 05-Nov-99 1378 3500 3110 0 750 650 397 3500 3500 1987 3550 0 0 50 0 0 635 450! 0 0 550 il4 3500 125 06-Nov-99 1386 3500 3110 0' 750 65~ 400 3500 3500 1998 3550 0 0 50 0 0 635 45C 0 0 550 113 3500 125 07-Nov-99 1385 3500 3110 0 750 65~ 401 3500 3500 1993 3550 0 0 50 C 0 635 45C 0 0 550 114 3500 125 08-Nov-99 1380 3500 3110 0 750 650 394 3500 3500 1978 3550 0 0 50 ' 0 0 635 45¢ 0 0 550 109 3500 125 09-Nov-99 1382 3500 3110 0 750 650 '396 3500 3500 1959 3550 0 0 50 C 0 635 45C 0 0 550 109 3500 125 10-Nov-99 1381 3500 3110 0 750 65~ 397 3500 3500 1964 3550 0 0 50 0 0 635 45¢ 0 0 550 109 3500 125 II-Nov-99 1379 3500 3110 0 750 650 393 3500 3500 1974 3550 0 0 50 C 0 635 45~ 0 0 550 Iii 3500 125 12-Nov-99 1376 3500 3110 0 750 650 391 3500 3500 1976 3550 0 0 50 0 0 635 45C 0 0 550 112 3500 125 13-Nov-99 1379 3500 3110 0 750 650 · 393 3500 3500 1976 3550 0 0 50 0 0 635 45C 0 0 550 109 3500 14-Nov-99 1383 3500 3110 0 750 650 392 3500 3500 1978 3550 0 0 50 0 0 635 45C 0 0 550 II0 3500 15-Nov-99 1373 3500 3110 0 750 650 388 3500 3500 1960 3550 0 0 50 . 0 0 635 45C 0 0 550 109 3500 12Y 16-Nov-99 1384 3500 3110 0 750 650 392 3500 3500 1979 3550 0 0 50 0 0 635 450 0 0 550, 112 3500 122 17-Nov-99 1369 3500 3110 0 750 650 387 3500 3500 1958 3550 0 0 $0 0 .0 635 45C 0 0 550 110 3500 12~ 18-Nov-99 1375 3500 3110 0 750 ' 650 387 3500 3500 1958 3550 0 0 50 0 0 635 45C 0 0 550 !12 3500 122 19-Nov-99 1359 3500 3110 0 750 650 381 3500 3500 1930 3550 0 0 50 0 0 635 45C 0 0 550 106 3500 12~ 20-Nov-99 1374 3500 3110 0 750 650 387 3500 3500 1950 3550 0 0 50 0 0 635 45C 0 0 550 112 3500 12~ 21-Nov-99 1375 3500 3110 0 750 650 387 3500 350C 1950 3550 0 0 50 ~ 0 635 45¢ 0 0 550 Iii 3500 12~ 22-Nov-99 1377 3500 3110 0 750 650 388 3500 3500 1958 3550 0 0 50 0 0 635 45C 0 0 550 115 3500 125= 23-Nov-99 1375 3500 3110 0 750 650 387 3500 350~ 1959 3550 0 0 50 C 0 635 45C 0 0 550 '115 3500 125 24-Nov-99 1388 3500 3110 0 750 650 389 3500 350(] 1973 3550 0 0 50 C 0 .635 45C 0 0 550 112 3500 125 25-Nov-99 1379 3200 3100 0 575 65C 387 3490 350C 1951 3500 ~ 0 50 C 0 645 450 .0 0 550 109 3490 '75 26-Nov-99 1385 3200 3100 0 575 65C 385 3~90 350C 1955 3550 0 0 50 C 0 645 450 0 0 550 !10 3475 75 27-Nov-99 1394 3200 310~ 0 575 65C 388 3500 350C 1963 3550 0 0 50 C 0 645 450 0 0 .550 113 3495 70 28-Nov-99 1398 3200 310C 0 575 65C 389 3500 350C 1963 3560 C 0 50 ¢ 0 645 450 0 0 550 116 3500 65 29-Nov-99 1391 3195 310~ 0 575 65~ 386 3490 350(] 1956 3550 C 0 50 C 0 645 450 0 0 550 114 3490 60 30-Nov-99 1392 3195 310C 0 575 65~ 384 3490 350C 1951 3550 ~ 0 50 £ 0 645 450 0 0 550 114 3490 60 T~TAL 41,207 0 '11,729 58,942 0 0 0 3,741 - MAXIMUM 3,500 3, l 10 750 650 3,500 3,500 3,560 0 50 0 , 645 450 0 550 3,500 140 AVERAGE 1,374 3,440 3,108 0 715 650 391 3,499 3,500 i.965 3,5~9 0 0 50 0 0 637 450 0 0 550 125 3.498 # DAYS 30 0 30 30 0 0 0 30 12/13/99 ~ .. i-23 shut in due to annular communication problem. ALASKA OIL AND GAS CONSERVATION COMMISSION September 20, 1993 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 Mr. P. T. Huckabee Staff' Production Engineer Shell Western E&P Inc. 601 West Fifth Ave., Suite 800 Anchorage, Alaska 99501 Re: ' Approval of an Alternate MIT for MGS wdl C24-23. Dear Mr. Huckabee: We received your letter of August 27, 1993 in which you requested Commission approval to use wellhead monitoring in MGS well C24-23 in lieu of pressure testing or survey logging to establish mechanical integrity. Tubing/casing communication was observed in MGS well C24-23 on June 11, 1992 and was reported to the Commission on that date. A following letter to the Commission, dated June 25, 1993, requested approval to continue injection. The letter stated that Shell would continue to monitor the .injection rate and pressure on a daily basis and would schedule a MIT by wellbore survey every two years. Shell's request was approved by the Commission on June 25, 1992. Your August 27, 1993 letter to the Commission states that the wellbore survey to prove MIT is now due, but you are unable to run the surey because there is a wireline fish in the hole. Therefore, you are requesting approval to use daily wellhead monitoring of injection rate and well head pressures in lieu of a survey. The basis for this request is Rule 9 Administrative Relief of AIO No. 9, which is as follows: Upon request, the Commission may administratively amend any rule stated above as long as the operator demonstrates to the Commission's satisfaction that sound engineering practices are maintained and the amendment will not result in an increased risk of fluid movement into an underground source of drinking water. Mechanical integrity testing is provided for in CFR 146.8. The approved methods of obtaining MIT Part 1 are listed in CFR 146.8(b)~ annulus pressure monitoring is provided for in Paragraph (b)(1). Thus, annulus pressure monitoring is acceptable to EPA for MIT Part I purposes. _.~., prin~ec~ on recyr:led paper Mr. P. T. Huckabee Shell Western E & P, Inc. September 20, 1993 Accordingly, the Commission approves your request to use daily wellhead monitoring and monthly reporting of injection rates and annulus pressures to satisfy MIT Part I requirements for MGS well C24-23. Sincerely, David Johns Chairman bew mits993 September 20, 1993 Mr. P. T. Huckabee Staff Production Engineer Shell Western E&P Inc. 601 West Fifth Ave., Suite 800 Anchorage, Alaska 99501 Re: Approval of an Alternate MIT for MGS Well, C24-23. Dear Mr. Huckabee: We received your letter of August 27, 1993 in which you requested Commission approval to use wellhead monitoring in MGS well C24-23 in lieu of pressure testing or survey logging to establish mechanical integrity. Tubing/casing communication was observed in MGS C24-23 on June 11, 1992 and was reported to the Commission on that date. A June 25,1992 letter to the Commission requested approval to continue injection stating that Shell would continue to monitor the injection rate and pressure on a daily basis and would schedule a MIT by wellbore survey every two years. This request was approved by the Commission on 6/25/92. Your August 27, 1993 letter to the Commission states that the wellbore survey to prove MIT is now due, but you are unable to run the surey because there is a wireline fish in the hole. Therefore you are requesting approval to use daily wellhead monitoring of injection rate and well head pressures in lieu of a survey. The basis for this request is Rule 9 Administrative Relief of AIO 9, which is as follows: Upon request, the Commission may administratively amend any rule stated above as long as the operator demonstrates to the Commission's satisfaction that sound engineering practices are maintained and the amendment will not result in an increased risk of fluid movement into an underground source of drinking water. Mechanical integrity testing is provided for in CFR 146.8. "Mechanical integrity". The approved methods of obtaing MIT Part 1 are listed in _CFR~(b); annulus pressure monitoring is provided in Paragraph (b)(1) lq6'~it0~ing of annulus pressure". Thus, annulus pressure monitoring is acceptable to EPA. In 1984 EPA conducted a study of "Methods for Determining the Mechanical Integrity of Class II Wells" which included Chapter 5. "Monitoring of Annulus Pressure". Based on data presented in "Table 3. ANNULUS PRESSURE MONITORING REQUIREMENT OF SELECTED STATES" daily monitoring with monthly reporting will provide a comparatively high level of monitoring - equal to or better than 10 of the 11 states listed. EPA's quarterly reporting form, 7520-3, provides for MITs Part 1 by annulus pressure monitoring under "VI. Summary of Mechanical Integrity, C. For Significant Leak, 1. Number of Annulus Pressure Monitoring Record Evaluations". Based on the above information and considerations, you have Commission approval to use wellhead monitoring of rate and pressures to satisfy MIT Part I requirements for MGS Shell well C24-23. Sincerely, David Johnston Chairman bew mits993 August 27, 1993 Shell Western E&P Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive c~-~ ~-.~ -~'~ Anchorage, AK 99501 ~z~-~j ~~F'~O 601 West Fifth Avenue · Suite 800 Anchorage, Alaska 99501 SUBJECT: MIDDLE GROUND SHOAL C24-23 MECHANICAL INTEGRITY COMPLIANCE Middle Ground Shoal (MGS) C24-23 is due for scheduled Mechanical Integrity Testings(MIT) this month (August 1993). A wireline fish in the tubing prevents MIT survey logging without excessive risk. We request approval to continue injection operations on MGS C24-23 by way of Administrative Relief provided by Rule 9 of Area Injection Order (AIO) No. 9.5 (dated 10/21/91), for a variance to Rule 6 (b.). Rule 6 (b) states: "As an alternative, injection/disposal wells may be survey-tested to verify that fluids injected (are) confined to designated injection strata using an EPA approved method every other year for wells with tubing-to-casing pressure communication. The proposed test method and detailed operations program shall be submitted to the Commission for approval on Form 10-403 prior to testing the well." ._MGS C24-23 is.operating.with tubinq/casing communications as summarized in n~tif~ca~ion correspondenCe to the-AOGCC ~ia letters dat'6d June 11, 1992 and June 25, 1992. Injectivity data demonstrates that mechanical integrity of the casing has been maintained. SWEPI will continue to operate the well in compliance with AOGCC regulations for reporting and monitoring. Mechanical integrity of the casing will be monitored and demonstrate~m~a EIVED JUSTIFICATION AUG 5 0 199 Alaska Oil& Gas Cons. Commissio~ Wireline operations to pull a dummy gas lift valve on Middle Ground Sho~nchomge (MGS) C24-23 in December 1992 resulted in the loss of the pulling tool assembly and 8000'+ of slickline. Injection operations have continued on the well and have not indicated any reduction in injectivity. Attached is the injection rate history for MGS C24-23 illustrating declining injectivity since the rig workover performed in August 1991 to repair tubing/packer integrity. Demonstration of tubing/casing annulus Mechanical Integrity was provided at the time of the workover via pressure testing. Prior to the workover, casing integrity was verified by an MIT logging survey completed November 26, 1989. The attached injection history illustrates that MGS C24-23 has a well established historical injectivity trend. The declining injectivity since the workover verifies that mechanical integrity of the casing has been maintained. Casing integrity failure will manifest itself by a rapid and certain increase in injectivity. Injection rates and pressures are monitored and recorded daily. Injectivity data is reported monthly to the AOGCC via Form 10-406. Additionally, daily injectivity data is submitted monthly to Blair Wondzell in compliance with AOGCC letter dated _November 6, 1993. A significant and unexplained increase in injectivity will ~ignal-a cause for concern of injection losses outside our designated injection strata. SWEPI will comply with Rule 7 of Administrative Approval No. 9.1, Area Injection Order No. 9 which requires that SWEPI must- 1) notify the AOGCC on the first working day following observation of a casing leak; 2) obtain Commission approval of a plan for corrective action; and 3) obtain Commission approval to continue injection. REQUEST FOR APPROVAL Based on the above information and justification, we request approval to continue injection operations on MGS C24-23 by way of Administrative Relief provided by Rule 9 of Area Injection Order {AIO) No. 9.5 (dated 10/21/gl), for a variance to Rule 6 {b.). Please notify us of approval or any required action to continue injection operations. If you have any questions or wish to discuss further, please call me at (907) 263-9646. Sincerely, P. T. Huckabee Staff Production Engineer RECEIVED AU G 3 0 1993 Alaska Oil & Gas (Sons. uumrniss~' Anchorage C24-23 10000 : : : 500 100 i [AU.~ :5 0 't99~) i Wa[er Injection Ra[e (Calendar Day)(bbls) ^~si~"fi'ii"g'.~'~i;'~iia':'ic,~°'~' ..................................... ~ Wot, r In'ech'on Pressure (psio) ......................... ~ j~nchOragei . · : ~ : : : _ " I ' I '""1 ..... ' I ' ' ' I "' I '' .... ' I"' I' '" ' ' I ' '1 ' ' '1 '" I ' "'" I '"1 '" ..... I .... ' '1'" '"'1 '-"'J .... ' I '" .... i "'" 68 69 70 71 72 73 74 75 76 77 78 79 80 81 82 83 84 85 86 87 88 89 90 91 92 93 WAM Fri Aug 27 15:01:11 1993 ALASKA OIL AND GAS CONSERVATION COMMISSION WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 November 6, 1992 P T Huckabee Staff Prod Engr Shell Wester E&P Inc 601 W 5th Av Ste 800 Anchorage, AK 99501 .~, Re: Injection Report MGS wells A12-12 and C24-2;~y Dear Mr Huckabee: As we discussed recently, it will be acceptable t° report the daily injection data on the subject wells to us once a month. Please continue to direct the report to my attention. Yours truly, Blair E Wond~.c~ll Sr Petr Engineer /jo\shellmgs Shell Western E&P In 601 West Fifth Avenue · Suite 800 Anchorage, Alaska 99501 June 30, 1992 Alaska Oil and Gas Conservation Commission ATTN' Lonnie Smith 3001 Porcupine Drive Anchorage, AK 9950] Gentlemen' SUBJECT' SUBMITTAL OF REPORT OF SUNDRY WELL OPERATIONS (FORM 10-404) FOR MIDDLE GROUND SHOAL WELL C24-23 Enclosed in duplicate is the Report of Sundry Well Operations to close the Sundry Approval No. 92-151 permitting temporary operation of the Middle Ground Shoal (MGS) well no. C24-23. Approval No. 92-161 was given June 25, 1992 for continued operation of MGS C24-23. If you have any questions or wish to discuss further, please call me at (907) 263-9646. Very Truly Yours, P.T~ Staff Production Engineer RECEIVED J UN 5 0 199t Alaska Oil & Gas Cons. comm~sS~or~ Anchorage 0 I G IN A L AL:~'~, OIL AND GAS CONSERVATION COMME N REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Pull tubing __ Stimulate Plugging__ Perforate __ Alter casing__ Repair well __ Other X 2. Name of Operator Shell Western E&P Inc. 3. Address 601 West 5th Avenue, Suite 810 Anchorage, Alaska 99501 5. Type o! Well: Development Exploratory Straligraphic Service X 4. Location of well at surface At top of productive interval Platform C, Leg 4, Conductor 32. 505.12'N and 1543.10'W of SE Corner of Sec.23, T8N, R13W, SM 426.5'N and 2507.86'E from SE Corner of Sec. 23, T8N, R13W, SM At effective depth At total depth 581.59'N and 2418'E from SW Corner of Sec. 23, T8N, R13W, SM 6. Datum elevation (DF or KB) 105'KB feet 7. Unit or Property name Middle Ground Shoal 8. Well Number C24-23 9. Permit number/approval number 68-107/92-1,,el 10. APl number 50-733-20145-01 11. Field/Pool MGS/"E","F", and "G" Pools 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 9555' feet Plugs (measured) 9407' feet 9475' feet J'unk (measured) 9328' feet Casing Length Size Cemented Structural Measured depth True vertical depth Conductor Surface 1830' 10-3/4",40.5#,J-55 1300sx Intermediate Production 9530' 7",26 & 29#, N-80 960sx 1830' 9530' Liner Perforation depth: measured 8108-9440' true vertical 7973-9294' (13 Intervals) Tubing (size, grade, and measured depth) 2-7/8", 6.5#, L-80 EUE 8rd 0'-8081' 3-1/2", 9.3#, N-80 EUE at 8081 '-8993' RECEIVED JUN ,~ 0 1992 Alaska 0ii & Gas Cons. (;0mrnission Anchorage Packers and SSSV (type and measured depth) Guiberson RH-1 Packer @ 8076', 8272', 8799', 8896', 8970' Baker "FHL" @ 8000' 13. ~' ..... '-" .... .. ..,,t ;q;:c.¢ze summary ~.;&llllEkal[.,41kl~.~ll VI ~k~l~l Intervals treated (measured) Approval #92-151 replaced by Approval ~J2-161 to continue Injection operations on 6/25/92. Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation ReDmsentative Daily Averaae Production orlniection Data OiI-Bbl Gas-Mcf Wate>Bbl Casing Pressure Tubing Pressure N/A N/A 679 0 3500 N/A N/A 663 3500 3500 15. Attachments: . 116. Status of well classification as: Copies of Logs and Surveys run II Oil__ Gas__ Suspendedm Injection Well Daily Report of Well Operations ~ Service I 17. I I~ereby certitY that the Toregoing is true and correct to the best cT my Knowlec~ge Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE June 25, 1992 Shell Western E&P Inc. Q 601 West Fifth Avenue · Suite 800 Anchorage, Alaska 99501 0 R ! G ! N A Alaska Oil and Gas Conservation Commission ATTN' Lonnie Smith 3001 Porcupi ne Drive Anchorage, AK 99501 Gentlemen- SUBJECT: SUBMITTAL OF APPLICATION FOR SUNDRY APPROVAL (FORM 10-403) TO CONTINUE INJECTION OPERATIONS ON MIDDLE GROUND SHOAL WELL C24-23 Enclosed in triplicate is the Application For Sundry Approval to continue injection operations on Middle Ground Shoal (MGS) well no. C24-23. SWEPI notified the AOGCC of pressure communication observation between the injection tubing and casing via letter dated June 11, 1992. Sundry Approval No. 92-151 was given to continue injection operations until June 25, 1992 while investigating the status of casing integrity. Pressure communication was observed and confirmed via annulus pressure observations on June 10, 1992. Injection rate and pressure has been monitored closely during the interim approval period and has not indicated a problem with casing integrity. A summary of the daily injection history from May 1, 1992 to June 23, 1992 is attached. Also attached is the monthly injection history through April 1992 since returning the well to injection following a workover in August 1991. SWEPI will continue to monitor injection rate and pressure on a daily basis and injection operations will be shut down immediately if the injectivity ~. increases significantly for unexplained reasons. Beginning June 29, 1992 a weekly injection report for MGS C24-23 will be included with the transmittal of the weekly injection report for MGS A12-12. In compliance with Rule 6, Area Injection Order (AIO) No. 9, Administrative Approval No. 9.5.b., we will schedule mechanical integrity logging survey tests every two years to verify the injection fluids are confined to the designated injection strata. Mechanical integrity was last verified in August 1991 via pressure testing. Our next mechanical integrity verification is scheduled for August 1993 via logging survey testing. If you have any questions or wish to discuss further, please call me at (907) 263-9646. Very Truly Yours, P. 1. Huckabee Staff Production Fn§ineer RECEIVED 2 1997. Cons. Commission STATE OF ALASKA AL~,,~KA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon Suspend__ Operation shutdown Re-enter suspended well Alter casing __ Repair Well __ Plugging __ Time extension Stimulate Change approved program __ Pull tubing __ Variance __ Perforate __ Other X 5. Type ct Well: 6. Datum elevation (DF or KB/ 2. Name of Operator Shell Western E&P Inc. Development 105' KB feet 13. Address 601 West 5th Avenue, Suite 800 Exploratory 7. Unit or Property name Anchorage, AK 99501 Stratigraphic ~ Middle Ground Shoal Service X 8. Well number 4. Location of well at Platform C, Leg 4, Conductor 32. 541.65'N & 1596.41'W of SE C24-23 surface corner of Sec.23, T8N, R13W, S.M. 9. Permit number At top of productive 426.5'N & 2507.86'E from SE corner of Sec.23, T8N, R13W, S.M. 68-107/92-151 interval 10. APl number At effective depth 50-733-20145-01 11. Field/Pool iAt total depth 581.59'N & 2418'E from SW corner of Sec. 23, T8N, R13W, S.M. MGS/"E", "F", and "G" Pools .... 12. Present well condition summary Total depth: measured 9555' feet Plugs (measured) true vertical 9407' feet -./~,~ -~ ~ppro~~'. Effective depth: measured 9475' feet Junk (measured) true vertical 9328' feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor Surface 1830' 10-3/4", 40.5#, J-55 1300ex 1830' Intermediate ProductionLiner 9530' 7", 26 & 29#, N-80 960sx 9530' ~ECEI yED Perforation Tubing (size, depth: grade, and measured measured 8108-9440' Alaska Oil &_ Gas Cons. Commission true vertical 7973-9294' (13 Intervals) 2-7/8", 6.5#, L-80 EUE 8rd 0' - 8081' ~Z~l~C/lOlag~ .. depth) 3-1/2", 9.3#, N-80 EUE at 8081' - 8993' Packers and SSSV (type and measured depth) Guiberson RH-1 Packer @ 8076', 8272', 8799', 8896',8970'. Baker "FHL" @ 8000' 13. Attachments Description summary of proposal X Detailed operations program __ BOP sketch 15. Status of well classification as: 14. Estimated date for commencing operation 06/25/92 Oil Gas Suspended 16. If proposal was verbally approved -- -- -- Service Injection Well Name of approver Date approved 117. I hereb~b_y certifl ,that the foregoing is true and correct to the best of my knowledge Signe~/-'3-~ '~' ~ Title Staff Production Engineer Date 06/25/92 ..... FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so repreSentative may witness I Approval / Plug integrity__ BOP Test Location clearance I Mechanical Integrity Test --Subsequent form require--d 10- ~-o ~- ~pproved Copy ..... -- Returned ORIGINAL SIGNED BY (., LONNIE C. SMITH Approved by order of the Commission Commissioner Date Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE MGS C24-23 Injection Stares May 1 - June 23, 1992 1May 711 ~ 0 2May see 3~)0 0 3May ~e 3soo 0 4~ ~ ~ 0 s~ ~ 3~ 0 6~ ~7 ~ 0 7~ ~ ~ 0 S~ ~ ~ 0 lo ~ ~ ~ o 11~ ~ ~ 0 13 ~y ~9 ~ 0 14~ ~ ~ 0 ~6~ ~4 ~ o 17~y ~ ~ o 19~ ~ ~ 0 ~ ~6 ~ 0 ~ ~ ~ 0 ~ ~0 ~ 0 2~ ~ ~7 ~ 0 ~ ~ ~ 0 ~y ~ ~, 0 27 ~ ~ ~ 0 ~ ~ ~ 0 ~ ~ ~ 0 31~ ~ ~1 0 1~ ~ ~ 0 2~ ~ ~ 0 3~ ~ ~ 0 4 ~ ~1 ~ 0 ~ ~ ~ 0 6 ~ ~1 ~ 0 7 ~e ~ ~ 0 8 ~e ~ ~ 0 9~ ~ ~ 0 13 ~e ~ ~ ~ 14~ ~7 ~ ~ 16~ ~ ~ ~ 17 ~ 679 ~ ~ 18 ~e ~ ~ ~ 19 ~ 670 ~ ~ PLATFORM: C C2~-25 10000 SO00 5O0 lO0 W'e[er InjecUon Rah (Calender ~/aJer Injc'ct. ion Pressure (psi(]) D O O D D D D O O D D D D D D D ................................................................--' ~-~' ~,...~.~. ........................ i .............................................................................................................. 7""'"' ............................................................. · ~' ...... -,¥"~i ....................................................................................................................................... ................................................................ >.....~....~. ................ R.....[......C......[....!.....v.......[....P ....................... I I I I I I ! I I I ~ ~ ~ /d3R M~Y JUN~JUL ~ ~ OCT NOV DEC JUN 2 5 1992 &las~ .Oil .& Gas Cons, commiSSion I I I I I I I I I FEB ~ ~PR ~Y JUN'JUL ~ ~ OCT NOV DEC PTH Thu Jun 25 06:40:44 1992 APPLICATION FOR SUNDRY APPROVAL (FORM 10-403) DESCRIPTION SUMMARY OF PROPOSAL MIDDLE GROUND SHOAL WELL NO. C24-23 SWEPI notified the AOGCC of pressure communication observation between the injection tubing and casing via letter dated June 11, 1992. Sundry Approval No. 92-151 was given to continue injection operations until June 25, 1992 while investigating the status of casing integrity. Through daily monitoring of injection rate and pressure, we have seen no indication of mechanical integrity failure of the casing. We propose injection operations continue on the subject well. Pressure communication was observed and confirmed via annulus pressure observations on June 10, 1992. Injection rate and pressure has been monitored closely during the interim approval period and has not indicated a problem with casing integrity. A summary of the daily injection history from May 1, 1992 to June 23, 1992 is attached. Also attached is the monthly injection history through April 1992 since returning the well to injection following a workover in August 1991. SWEPi will continue to monitor injection rate and pressure on a daily basis and injection operations will be shut down immediately if the injectivity increases significantly for unexplained reasons. Beginning June 29, 1992 a weekly injection report for MGS C24-23 will be included with the transmittal of the weekly injection report for MGS A12-12. In compliance with Rule 6, Area Injection Order (AIO) No. 9, Administrative Approval No. 9.5.b., we will schedule mechanical integrity logging survey tests every two years to verify the injection fluids are confined to the designated injection strata. Mechanical integrity was last verified in August 1991 via pressure testing. Our next mechanical integrity verification is scheduled for August 1993 via logging survey testing. RECEIVED JUN 2,5 199~ J~Jas~ka .Oil .& Gas Co~s, Commission ~horage jUne 11, 1992 Shell Western E&P Inc. 601 West Fifth Avenue · Suite 800 Anchorage, Alaska 99501 Alaska Oil and Gas Conservation Commission ATTN' Lonnie Smith 3001 Porcupine Drive Anchorage, AK 99501 ~ ~t -t° 7 Gentlemen: SUBJECT: MIDDLE GROUND SHOAL WELL C24-23 NOTIFICATION OF TUBING/CASING COMMUNICATION OBSERVATION RULE 7, AREA INJECTION ORDER No. 9, ADMINISTRATIVE APPROVAL 9.1 In compliance with Rule 7 of Area Injection Order (AIO) No. 9, Administrative Approval No. 9.1, we are notifying you of pressure communication observation between the injection tubing and casing in MGS well no. C24-23. Pressure communication was observed and confirmed via annulus pressure observations on June 10, 1992. Injection rate monitoring has not indicated a problem with casing integrity. Enclosed in triplicate is an Application for Sundry Approval (Form 10-403) to continue injection operations on the subject well. Verbal approval to continue injection operations until June 25, 1992 (while investigating the status of casing integrity) was given by Blair Wondzell on June 11, 1992. Injection rate will be monitored closely during this interim approval period and injection operations will be shut down if the injectivity increases by 15% or more. Under normal operating conditions, C24-23 has averaged injectivity of 671 BPD at 3500 psi over the latest 14 representative days. Injection rate for June 10, 1992 was 683 BPD at 3500 psi. If the injection rate exceeds 772 BPD = (671 x 1.15) for unexplained reasons, injection operations on this well will be terminated. Following further evaluation of casing integrity during the interim approval period, we will submit another Form 10-403 requesting approval for continued long-term injection operation. If you have any questions or wish to discuss further, please call Paul Huckabee at (907) 263-9646. Very Truly Yours, S. B. Brown-Maunder Sr. Environmental Technician Shell Western E&P Inc. RECEIVED JUN 1 2 1992 Alaska 0il & Gas Cons. Commission Anchorage ' ' ""~'" STATE OF ALASKA o., oouu,s , , 0 fl I G I N A L .,. APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon Suspend__ Operation shutdown Re-enter suspended well Alter c, asing Repair Well Plugging __ Time extension Stimulate Change approved program m Pull tubing Variance Perforate __ Other X 5. Type ct Well: 6. Datum elevation (DF or KB~ 2. Name of Operator Shell Western E&P Inc. Development 105' KB feet 3. Address 601 West 5th Avenue, Suite 800 Exploratory 7. Unit or Property name Anchorage, AK 99501 Stratigraphic __ Middle Ground Shoal Service X 8. Well number 4. Location of well at Platform C, Leg 4, Conductor 32. 541.65'N & 1596.41'W of SE C24-23 surface corner of Sec.23, T8N, R13W, S.M. 9. Permit number At top of productive 426.5'N & 2507.86'E from SE corner of Sec.23, T8N, R13W, S.M. 68-107 interval 10. APl number At effective depth 50-733-20145-01 11. Field/Pool At total depth 581.59'N & 2418'E from SW corner of Sec. 23, T8N, R13W, S.M. MGS/"E", "F", and "G" Pools 12. Present well condition summary Total depth: measured 9555' feet Plugs (measured) true vertical 9407' feet Effective depth: measured 9475' feet Junk (measured) true vertical 9328' feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor Surface 1830' 10-3/4", 40.5#, J-55 1300sx 1830' Intermediate Production 9530' 7", 26 & 29#, N-80 9608x 9530'~ ~C ~ I V t~ L~ Liner Perforation depth: measured 8108-9440' JUN 1 2 1992 true vertical 7973-9294' (13 Intervals) Alaska 0tl & Gas Cons. (;0mmisslo~ Tubing (size, grade, and measured depth) 2-7/8", 6.5#, L-80 EUE 8rd 0'- 8081' Anchorage 3-1/2", 9.3#, N-80 EUE at 8081' - 8993' Packers and SSSV (type and measured depth) Guiberson RH-1 Packer @ 8076', 8272', 8799', 8896',8970'. Baker "FHL" @ 8000' 13. Attachments Description summary of proposal ~ Detailed operations program __ BOP sketch 14. Estimated date for commencing operation 06/10/92 15. Status of well classification as: Oil Gas Suspended 16. If proposal was verbally approved Blair Wondzell (Approval expires 6/25/92) 06/11/92 Service Injection Well Name of approver Date approved 17. I hereby_certify that the foregoing is true and correct to the best of my knowledge Signed ..~(~...__O ~~ Title Staff Production Engineer Date 06/11~/92 FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness I Approval No. Plug integrity.__ BOP Test Location clearance Mechanical Integrity Test.__ --Subsequent form required 1 O- ~---/',~ Approved by order of the Commission LONNtE C. SMITH Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE APPLICATION FOR SUNDRY APPROVAL (FORM 10-403) DESCRIPTION SUMMARY OF PROPOSAL MIDDLE GROUND SHOAL WELL NO. C24-23 In compliance with Rule 7 of Area Injection Order (AIO) No. 9, Administrative Approval No. 9.1, we are notifying you of pressure communication observation between the injection tubing and casing in MGS well no. C24-23. Pressure communication was observed and confirmed via annulus pressure observations on June 10, 1992. Injection rate monitoring has not indicated a problem with casing integrity. Verbal approval to temporarily continue injection operations on this well (until June 25, 1992 while investigating the status of casing integrity) was given by Blair Wondzell on June 11, 1992. Injection rate will be monitored closely during this interim approval period and injection operations will be shut down if the injectivity increases by 15% or more. Under normal operating conditions, C24-23 has averaged injectivity of 671 BPD at 3500 psi over the latest 14 representative days. Injection rate for June 10, 1992 was 683 BPD at 3500 psi. If the injection rate exceeds 671 x 1.15 : 772 BPD for unexplained reasons, injection operations on this well will be terminated. Following further evaluation of casing integrity during the interim approval period, we will submit another Form 10-403 requesting approval for continued long-term injection operation. RE(ElVED JUN 1 2 1992 Alaska Oil & (~as Cons. oommiss'm~ Anchorage 601 West Fifth Avenue Suite 800 Anchorage, Alaska 99501 December 16, 1991 State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Gentlemen: SUBJECT: SUBSEQUENT REPORT FOR MIDDLE GROUND SHOAL WELL C24-23 Enclosed are duplicates of the Subsequent Report for the recently completed stimulation work of Middle Ground Shoal well C24-23. The operations were completed on October 19, 1991. If you need additional reports or information, please contact Mr. Paul Huckabee at (907) 263-9646. Very Truly Yours, Manager Alaska Operations Western Division RGB/SBBM/dlw Enclosures SBBM~12169 lA. WP5 RECEIVED DEC 20 1991 Alaska 0il & Gas Cons. Commisslen Anchorage STATE OF ALASKA REPORT OF SUNDRY WELL OPERATI 1. Operations performed: Operation shutdown m Stimulate X Plugging__ Perforate w Pull tubing X Alter casing Repair well X Other 5. type o! Well: 6. Datum elevation (DF or KB) 2. Name of Operator Shell Western E&P Inc. Development 105'KB feet 3. Address 601 West 5th Avenue, Suite 810 Exploratory 7. Unit or Property name Anchorage, Alaska 99501 Stratigraphic Middle Ground Shoal Service X 8. Well Number 4. Location of well at surface Platform C, Leg 4, Conductor 32. 505.12'N and 1543.10'W C24-23 of SE Corner of Sec.23, T8N, R13W, SM 9. Permit number/approval number At top of productive interval 426.5'N anti 2507.86'E from SE Corner of Sec. 23, TSN, 68-107/91-184 R13W, SM 10. AP! number At effective depth 50-733-20145-01 581.59'N and 2418'E from SW Corner of Sec. 23, T8N, 11. Field/Pool At total depth R13W, SM MGS/"E","F", and "G" Pools 12. Present well condition summary Total depth: measured 9555' feet Plugs (measured) true vertical 9407' feet Effective depth: measured 9475' feet Junk (measured) true vertical 9328' feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor Su dace 1830' 10-3/4",40.5#,J-55 1300sx 1830' Intermediate Production 9530' 7",26 & 29#, N-80 960sx 9530' LinerRECEIVED Perforation depth: measured 8108-9440' DEC 20 991 true vertical 7973-9294' (13 Intervals) Alaska 0ii & Gas Corls. Commissien Tubing (size, grade, and measured depth) 2-7/8", 6.5~, L-80 EUE 8rd 0'-8081' Anchorage 3-1/2", 9.3~, N-80 EUE at 8081'-8993' Packers and SSSV (type and measured depth) Guiberson RH-1 Packer @ 8076', 8272', 8799', 8896', 8970' Baker "FHL" @ 8000' 13. Stimulation or cement squeeze summary Intervals treated (measured) 8702' - 9440' Treatment description including volumes used and final pressure CTU Acid soak, wash, squeeze. Total acid volume 127 bbls. Squeeze ISIP = 2750 psi. 14. Representative Daily Averaoe Production or Injection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation N/A N/A 976 3500 3500 Subsequent to operation N/A N/A 1015 0 3500 15. Attachments 16, Status of well classification as: Copies of Logs and Surveys run -~- Oil Gas Suspendedw Service Injection Well Daily Report of Well Operations __ g -- 17. I hereby certity hat the toregomg ~s true an(~ correct to tl~e oest o! my Knowleclge Signe(J'~....~ ,,.~~ Title%~ ~"v.c>~,-c...'r~.~ ~--~',.',~..,~..~-. Date I~ 1,~ i~A~ Form 10-404 Rev ~.6/15/88 SUBMIT IN DUPLICATE DAILY REPORT WELL: C24-23 DAILY SUMMARY - (from 0600 hrs prior day to 0600 hrs) 08/01/91 - RIG UP SLICKLINE. TEST LUBRICATOR T/3500 PSI. SWAB VALVE LEAKS AT 1900 PSI. HELD 1900 PSI OK FOR 15 MINS. RIH W/2.70 GAGE RING T/8079'. POH. PUT ON 2.60 GAGE RING, RIH T/8079'. POH AT RPT TIME. - THIS REPORT 6 HRS. - NO ACCIDENTS REPORTED. 08/02/91 - FINISHED POH W/2.60 RING GAGE. RIH W/2.20 THRU EOT T/9020'. POH. RIH W/2.30 RING GAGE, ALSO ABLE TO GO THRU TBG T/9020'. POH. RIH W/2.75 RING GAGE T/TAG UP ON SLIDING SLEEVE. DID SO AT 8042' WIRELINE DEPTH. POH. RIH W/PX PLUG, SET IN X-NIPPLE AT 8073' (WLM) POH. RIH, SET PRONG IN PX PLUG. POH. RIG WIRELINE ASIDE. - RIG UP TO TEST FOR COMMUNICATIONS BETWEEN TBG/ANNULUS. BLED DOWN PRESS FROM ANNULUS T/PROD HEADER FROM 1500 PSI T/1000 PSI. TBG PSI WENT DOWN FROM 1500 PSI T/1300 PSI. SHUT IN, PRESSURES EQUALIZED IN 30 MINS. AT 1500 PSI. BLED ANNULUS T/500 PSI, TBG CAME DOWN T/1300 PSI AND STAYED THIS WAY WHILE CONTINUING TO BLEED OFF FLUID. SHUT IN. PRESSURES EQUALIZED IN 30 MINS AT 1500 PSI. - RIG UP SLICKLINE. TEST LUBRICATOR T/1900 PSI. RIH W/2" JDC & PULLED PRONG. POH. MADE UP GS PULLING TOOL. RIH, FAILED TO PULL PX PLUG. POH. REDRESS TOOL, RIH, FAILED TO RETRIEVE PX PLUG AGAIN. REDRESS TOOL. RIH FAILED TO PULL PX PLUG AGAIN. - WAITING ON WIRELINE TOOLS. PREP F/NIPPLE UP BOPE WHILE WAITING. - CLEANED PITS, PREP T/MIX KILL WEIGHT MUD. - NO ACCIDENTS REPORTED. 08/03/91 - WAIT ON WIRELINE TOOLS. MIXING UP 13.0 PPG KILL MUD WHILE WAITING. - MADE RUNS W/2" AND 1.5" HYDROSTATIC BAILERS TO CLEAN SCALE FROM TOP OF PX PLUG IN X-NIPPLE AT 8073' WLM. ATTEMPT TO REMOVE PX PLUG W/GS TOOL. DID NOT. BAILED W/PUMP TYPE BAILER, RECOVERING SCALE EACH TRIP. LAST TRIP HAD VERY SMALL AMOUNT OF SCALE. RAN 3" GS TOOL AGAIN. STILL DID NOT RECEIVED DEC 0 1991 Alaska Oil & 6as Cons. comm~SS~O~ Anchorage DAILY REPORT WELL: C24-23 08/03/93. ( CONT ' D) RECOVER PX PLUG. SEEM TO BE KNOCKING AS MUCH SCALE ONTO PX PLUG EACH TRIP AS IS BEING RECOVERED. RIG DOWN SLICK LINE. - RIG UP WESTERN ATLAS. TEST LUBRICATOR T/1900 PSI F/15 MINS. OK. RIH W/2.125", 5 SHOTS PER 2' TUBING PUNCH. SHOT F/8050' T/8052'. POH. RIG W-A ASIDE. - NOTE: MIXING 13.0 PPG KILL MUD, CNG RAMS T/VARIABLES WHILE WIRELINING. - NO ACCIDENTS REPORTED. 08/04/91 - BLEED DOWN ANNULUS T/600 PSI THRU PROD SYS, TBG PSI TRACKED WITH ANNULUS PSI. SHUT IN ANNULUS. ISIP WAS 700 PSI. TBG/ANNULUS TRACKED TOGETHER AT CONSTANT RATE BACK UP T/1400 PSI IN 30 MINS. - RIGGED UP SLICKLINE. MADE 2.70 GAGE RING RUN THRU PERFS AT 8050'/8052' TO ASCERTAIN COULD STILL RUN 2.70 JET CUTTER THRU PERFED AREA TO CUT BELOW PERFS. TAGGED UP AT 8072 WLM. (8068' PROG EQUIP DETAIL DEPTH). - NOTE: PERF DEPTH GIVEN ABOVE IS PROG EQUIP DETAIL DEPTH. - POH. RIG DN. - RIG UP W-A. TEST LUBRICATOR T/1900 PSI. RIH W/2.70" JET CUTTER. CUT AT 8063', PROG DEPTH, POH. RIG DOWN W-A. - CONTINUE W/ONGOING KILL MUD MIXING OPERATIONS. RIG UP T/PUMP DOWN TBG TAKING RETURNS T/PROD HEADER OR RIG CHOKE MANIFOLD AS NEEDED. TEST LINES T/4000 PSI. RIGGED UP H2S SCAVENGER PUMP DOWN STREAM OF ANNULUS. - HELD SAFETY/OPERATIONS DETAIL MEETING W/DRLG/PROD PERSONNEL. DISCUSSED KILL OP'S, PLANS F/H2S IN RETURNS ETC. - PUMPING KILL WT MUD (13.0 PPG) AT RPT TIME, 2 BBLS MIN TO PROD SYS. NO H2S ENCOUNTERED THRU BOTTOMS. - NO ACCIDENTS REPORTED. 08/05/91 - FINISHED KILLING WELL. PUMPED 300 BBLS T/PROD. CNG RETURNS T/PITS, CIRC/COND UNTIL HAD 12.9 PPG RETURNS. NO H2S ENCOUNTERED. - PICKED UP 288 JTS 3.5" DP F/WORK STRING WHILE MONITOR WELL AND WEIGHT UP DRLG MUD BROUGHT OVER T/ACTIVE SYSTEM F/STORAGE TANK. WELL STATIC. RECEIVED DEC 1991 .Oil & Gas Cons. Comm'tssion chorage DAILY REPORT WELL: C24-23 08/05/91 - NIPPLE DOWN TREE. NIPPLING UP BOPE AT REPORT (CONT'D) TIME. - NO ACCIDENTS REPORTED. 08/06/91 - FINISH NIPPLING UP BOPE. - TBG HANGER/LDG JT CONN WOULD NOT ALLOW TESTING OF BOP. TESTED CHOKE MANIFOLD EQUIP, ACCUMULATOR OK. - CIRC/COND 13.0 PPG MUD AROUND. WELL STATIC. - POH, LAYED DOWN 220 JTS 4.5" SEAL-LOCK TBG. SEAL AREA CORRODED AWAY IN 1/2 MOON SHAPE, 25 CENT PIECE SHAPE/SIZE ON ABOUT 50% OF THEM AT NO CERTAIN DEPTH, RATHER, RANDOM TOP T/LAST JT. LAYED DOWN 27 JTS AND SHOT/CUT JT OF 3.5" TBG. NO NOTICEABLE CORROSION. THE 5 HOLES THAT WERE SHOT WERE AT 8050'-8052' AND THE CUT WAS AT 8063~ EXACTLY PER SLM OUT. CUT OFF WAS MADE BY JET CUTTER AND THE CUT WAS FLARED 5/16 OF AN INCH MORE THAN THE 3 1/2" O.D. OF THE TUBE. - TEST BOPE 250/2500 PSI. OK. - MAKE UP BHA: ROTARY SHOE, 20' WP EXT, SCRAPER, JARS, 9 DC'S, INTENSIFIERS, 3.5" X-95 13.30# DP. TIH AT RPT TIME. - NO ACCIDENTS REPORTED. 08/07/91 - FINISHED TIH W/SCRAPER/MILL ASSMY. - KELLY UP, MILL OVER THE 2 TBG COLLARS ON THE "X- NIPPLE" AT 8072' (DP MEASUREMENT) TAG TOP OF PACKER AT 8081' DP MEASUREMENT. - NOTE: ALL DEPTHS GIVEN WILL BE DRILL PIPE DEPTHS UNLESS OTHERWISE NOTED. DRILL PIPE DEPTHS ARE 3' DEEPER THAN PROGNOSIS/TBG DEPTHS. - FINISHED CIRC UNTIL HAD BOTTOMS UP. - POH, STAND ASIDE FISHING BHA. - MAKE UP HOWCO RTTS, TIH T/8000', SET RTTS. - TEST CST T/2000 PSI FOR 30 MINS. OK. - POH, LAY DOWN RTTS. - MAKE UP HOMCO OUTSIDE TBG CUTTER ASSMY, TIH. TIGHT SPOT AT 8049'. - TRY TO WORK PAST TIGHT HOLE AT 8049. NO SUCCESS. - POHW/OUTSIDE CUTTER ASSMY AT REPORT TIME. - NO ACCIDENTS REPORTED. 08/08/91 - FINISHED POH. LAYED DOWN BOTH STABS FROM BHA. - TIH W/MECHANICAL OPERATED OUTSIDE TBG CUTTER. - ATTEMPT T/CUT AT 8076' CUTTER BLADE DEPTH. RECEIVED DEC 20 1991 Alaska Oil & E~as Cons. Commission Anchoraae DAILY REPORT WELL: C24-23 08/08/91 - POH, NO RECOVERY. LAYED DOWN MECHANICAL CUTTER. (CONT'D) MADE UP HYDRAULIC OUTSIDE CUTTER. TIH. - TRY TO CUT TBG AT 8077'. NO SURFACE INDICATIONS THAT TBG WAS CUT. PULLED UP AGAINST BOTTOM OF THE COUPLING ON THE PUP BETWEEN X-NIPPLE AND PACKER WITH THE CUTTER BLADES AND ROTATED UNTIL COULD PICK UP FREE. - POH. RECOVERED 8.35' OF 3 1/2" TBG, X-NIPPLE AND _ THE COUPLING FROM THE PUP ON THE PACKER. 9.85' OVERALL. TOF NOW AT 8076 DP DEPTH. THIS LEAVES THE 6' PUP ABOVE THE TOP MOST PACKER LOOKING UP. (PX PLUG WAS ALSO RECOVERED INSIDE THE X-NIPPLE) - LAY DOWN FISH/CUTTER ASSMY. MAKING UP TAPER MILL ASSMY AT RPT TIME. 08/09/91 - FINISHED TIH W/STABILIZED TAPERED MILL ASSMY. - CDL 100'. - DRESS 4" OFF OF TBG W/MILL AT 8076'. - CIRC BOTTMS UP. - POH W/TAPER MILL ASSMY. - TIH W/SBR ON END OF DP. - RIG UP SLICKLINE. MADE 2.30 STAR BIT RUN T/8930' WLM. (COINCIDES WITH LOCATION OF KGB MANDREL #4 AT PROG DEPTH OF 8932') UNABLE TO WORK PAST 8930' W/2.30" STAR BIT. POH. RIH W/2.25" IMPRESSION BLOCK. TAGGED UP ON/IN TBG STUB AT 8076'. POH, HAD A CUT 1.5" LONG INTO BLOCK ON 1 SIDE. - NOTE: OF THE 2 OUTSIDE CUTTERS RAN THERE WERE 12 KNIVES, 1.5" LONG BY .875" WIDE BY .375" THICK LOST IN HOLE. ALSO LOST 6 SPRING DOGS OUT OF THE MECHANICAL OUTSIDE CUTTER. 5" LONG BY 1" WIDE BY .125 THICK. - RIG WIRELINE EQUIPMENT ASIDE. - POH W/SBR. TIHW/STABILIZED TAPERED MILL ASSMY TO DRESS OFF TBG STUB. - NO ACCIDENTS REPORTED. 08/10/91 - FINISHED TIH W/STABILIZED TAPERED MILL T/TOP OF 3.5" STUB AT 8076'. - MILLED OFF 2' OF 3.5" TBG TO REMOVE PORTION DAMAGED BY PRIOR CUTTING WITH OUTSIDE CUTTERS. TOP OF STUB NOW AT 8078'. CIRC HOLE CLEAN. - POH W/MILL ASSMY. STAND IT ASIDE IN DERRICK. MAKE UP SBR ON END OF DP TIH, LAND SBR OVER 3.5" TBG STUB AT 8078', TAG PKR AT 8081'. RECEIVED DE(] 1991 Alaska Oil & Gas Cons. Comm~sS~en Anchorage DAILY REPORT WELL: C24-23 08/10/91 - RIG UP SLICKLINE. RIH W/2.25" MAGNET T/8930'. (CONT'D) POH. NO RECOVERY. RIH W/2.25" IMPRESSION BLOCK T/OBSTRUCTION AT 8930, POH. HAD 3/4" LONG BY 1/16TH WIDE MARK IN CENTER OF IMPRESSION BLOCK. RIH W/BARBED SPEAR W/3/4" O.D. SHAFT. ALSO HAD 4 PIECES OF .125 WIRE 3/4" LONG SPOT WELD THRU HOLES IN SPEAR SHAFT. WORKED ON OBSTRUCTION AT 8930'. DID NOT GET PAST IT. HAD IT TO HANG UP A FEW TIMES BUT ALWAYS CAME LOOSE. POH. - WIRELINE UNIT BLEW A SEAL. REPAIR SAME. - RIH W/IMPRESSION BLOCK W/LIMBER HOOK UP. HIT 3.5" STUB AT 8078'. POH. WENT BACK T/STIFF SINKER BAR HOOK UP. RIH OK T/8930'. POH. SHOWED HAD OBSTRUCTION IN MIDDLE OF HOLE. LAY DOWN LUBRICATOR, CHANGING OUT THE PACKOFF PACKING AT REPORT TIME. - HELD TRIP DRILL W/BOTH CREWS. WELL SECURED IN 1 MIN EACH TIME. - NO ACCIDENTS REPORTED. 08/11/91 - REHEAD WIRELINE. RIH T/8930' W/MAGNET, POH, NO RECOVERY. RUN DUMMY 2.125" PERF GUN T/8925' OK. POH. RIG ASIDE SLICKLINE. - CIRC BOTTMS UP. - POH, LAYED DOWN SBR. - BROKE DOWN/LAYED DOWN HOMCO TOOLS. PULLED WEAR BUSHING. - RIG UP TBG RUNNING EQUIP. RUNNING 2 7/8" TBG ---- (CNG VARIABLE RAMS TO 2 7/8"), TAGGED UP ON TOP MOST PACKER AT 8081' NEW TBG MEASUREMENT. - RIG UP SLICKLINE. RUN DUMMY PERF GUN T/8200' TO ASCERTAIN SBR IS OVER TBG STUB AT 8078'. RIG SLICKLINE ASIDE. - INSTALL/LAND TBG HANGER W/4' PUP UNDER HANGER. IT IS 37.85' FROM TOP OF HANGER TO KB. - NOTE: TOP OF FISH NOW REPORTED AS THE OBSTRUCTION AT GLM #4:(8930 WLM) - NO ACCIDENTS REPORTED. 08/12/91 - RIG UP SLICKLINE. RAN DUMMY PERF GUN T/8200' OK. POH. RIG ASIDE. - TEST LINES T/3000 PSI. PUMP 35 BBL POLYMER PILL AHEAD OF FIW, CIRC WELL CLEAN HOLDING 2000 PSI SURFACE BACKPRESSURE. SPOTTED VISCO 3900 MIXED IN FIW AT .04% BY VOLUME IN ANNULUS. HAD 1550 PSI ON WELL WHEN STOPPED PUMPING. R E~EIV E D DEC 1991 Alaska Oil & Gas Cons. Commission ;Anchorage DAILY REPORT WELL: C24-23 08/12/91 - RU SLICKLINE. RAN PXN PLUG/PRONG, SET IN XN (CONT'D) NIPPLE AT 8038'. - PRESSURE UP ON TBG T/3000 PSI SETTING BAKER FHL PACKER AT 8000'. (TOP) BLED OFF TBG, PXN PLUG HOLDING OK; BLED ANNULUS T/O PSI; PKR SET OK. INSTALL CHART ON RECORDER, TEST ANNULUS T/2200 PSI FOR 30 MINS. OK. FAXED RESULTS T/AOGCC PER THEIR REQUEST. - NIPPLE DOWN BOPE. NIPPLE UP TREE. CAMERON REP TESTED TBG HANGER AND FLANGE BODY ON TREE T/3000 PSI. OK. SET 2 WAY CHECK AND TEST VALVES ON TREE T/5000 PSI. OK. - RIG UP SLICKLINE. PULLED PXN PLUG/PRONG FROM XN NIPPLE AT 8038'. - RIG DOWN SLICKLINE. - RELEASED RIG AT 0600 HRS 08/12/91. - COMPLETION EQUIPMENT DETAIL: (UP WEIGHT WAS 80,000, DOWN WAS 65,000) (WEIGHT INCLUDES BLOCKS ) - BAKER "SBR" AT 8081'. - 1 JOINT OF 2 7/8" TBG (6.5# L-80 8RD EUE) ALL TBG SAME - OTIS "XN" NIPPLE (2.205" I.D.) AT 8038' - 1 JOINT OF 2 7/8" TBG. - BAKER FHL HYD. RET. PACKER, 50,000# SHEAR AT 8000' (TOP OF PKR) - 2 7/8" TO 3 1/2" XO TO PBR - BAKER PBR SEAL BORE, SHEAR AT 33150# AT 7981' - 1 JOINT OF 2 7/8" TBG. - OTIS "X" NIPPLE AT 7948'. - 242 JOINTS OF 2 7/8" TBG. - OTIS "X" NIPPLE AT 355'. - 10 JOINTS OF 2 7/8" TBG. - 4' PIN BY PIN PUP JOINT. - CAMERON TYPE "D" TBG HANGER - NO ACCIDENTS REPORTED 10/18/91 - ASSIGN COIL TUBING OPERATIN TO THIS WELL AT 0800 HRS, 10/18/91. - R/D & MOVE RIG TO LEG #4. R/U ON C24-23 @ 2000 HRS, 10/18/91. - CONFIRM WIRELINE FISH (TBG CUTTER FINGERS) HAVE BEEN KNOCKED OUT OF TUBING. - RIG W/2.0" TAPERED MILL & 1.75" PDM, DBLCV. RECEIVED DEO 1991 AlasJ .Oil & Gas Cons. CommisSiOn Anchorage DAILY REPORT WELL: C24-23 10/18/91 - OBSERVED SMALL "BUMP" @ 8078' (RKB). P/U & RUN (CONT'D) TAPERED MILL THROUGH THIS REGION (50' BOTH SIDES) TO MILL ANY UPSET LIP THAT MAY HINDER WIRELINE ACCESS. - TAG & MILL BRIDGE @ 9098'. MILL 45' OF SOFT FILL F/9142' T/9200'. SPOT & PUMP 3 bbl SWEEP @ 9252'. TAG PBTD @ 9454', PUMP 3 bbl SWEEP. CHASE SWEEP & POOH W/TAPER MILL & PDM ASMY AT REPORT TIME. 10/19/91 - RIH & JET WASH @ 35 gpm W/2.0" SWIRL TYPE JET WASH NOZZLE & DBLCV. NO PROBLEM @ TBG STUB. TAG BOTTOM @ 9455'. - P/U @ 9453', PUMP 5 BBL GEL SWEEP. RECEIVE HEAVY SCALE & CACO3 RETURNS FROM SWEEP. CAPTURE RETURNS TO SURGE TANK. - PUMP 18 bbls 7.5% HCL SOLUTION AND SPOT F/9440' T/8702' TO SOAK PERFORATIONS. SOAK FOR 30 mins. - RECEIVE FOAMED RETURNS, H2S @ 600 ppm. EVIDENCE OF WELL BACK FLOWING. - LOCATE NOZZLE @ 9440'. JET WASH WITH ACID WHILE HOISTING @ 20 fpm, 1 bpm, TO 8756'. - STOP PUMP & RIH, TAG FILL @ 9440', (14' OF FILL). - JET WASH T/9454'. - CHASE WITH 5 bbl XCD POLYMER GELL SWEEP, 20 bbls FIW, AND 5 bbl SWEEP TO CLEAR WELLBORE & TBG FOR INJECTION QUALITY CLARITY. - CONDUCT WELL PRESSURE INTEGRITY & INJECTIVITY TEST. CSG @ 110#, PTbg @ 2130# @ 48 gpm (25 bbls). GOOD. - PUMP 7.5% HCL SOLUTION TO EOCT. CLOSE IN WELL. PUMP 75 bbls ACID, DISPLACE TO FORMATION WITH 100 bbls OF FIW. - SQUEEZE DATA: CSG# CT# PTbg# GPM ISIP = 2750# LOW 0 4800 1850 42 5m SIP = 2650# HIGH 150 5000 2700 54 10m FSIP = 2350# - POH W/JET WASH NOZZLE AT REPORT TIME. - R/D LUBRICATOR, MOVE TO C42-23. COIL TUBING OPERATION ASSIGNED TO C42-23 @ 1800 hfs, 10/19 RECEIVED DEO ~0 1991 Alaska.Oil & Gas Cons. Commisslen ~,ncJiorage Shell Western E&P Inc. 601 West Fifth Avenue · Suite 800 Anchorage, Alaska 99501 . August 7, 1991 Ms. Joan Miller State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99502 Dear Ms. Mil 1 er' SUBJECT: MONTHLY INJECTION REPORT FOR THE MIDDLE GROUND SHOAL FIELD (MGS) FOR THE MONTH OF JULY, 199] The Monthly Injection Report for the Waterflood project at MGS for July is enclosed in duplicate. If you have any questions regarding this report, please call Ms. Susan Murnan at (907) 263-9614. Very truly yours, W. F. Simpson Manager Regulatory Affairs Alaska Division WFS/slm Enclosures $~s Go~S. \AOGCC\MTHL¥INJ. JULY STATE OF ALASKA ALASICA OIL AND GAS CONSERVATION COMMISSION MONTHLY INJECTION REPORT 20 AAC 25.432 SHELL WESTERN E&P INC. Name of Operator MIDDLE GROUND SHOAL Field and Pool JULY, 1991 Month and Year of Injection TUBING PRESSURE 1. 2. 3. 4. 5. 6. ?. Wet[ # API# CLass Field & Days in MAX Average 50- Pool Code Operation PSIG PSIG A 11-i2 733-10083-00 W 524114 31 3,550 3,502 A 11-13 733-20007-01 W 524114 31 3,550 3,502 A 12-12 733-20044-00 W 524114 31 3,550 3,502 A 23-01 733-20238-00 ~ 524114 31 3,550 3,502 A 33-14 733-20057-00 W 524114 31 3,550 3,502 A 34-11 T53-10084-01 g 524114 31 4,400 4,348 A 34-14 733-10086-01 ~ 524114. 31 3,550 3,500 A 44-11 733-20027-00 ~ 524114 0 N/A N/A · C ~-26 733-20071-00 W 524114 31 3,500 3,500 C 24-23 733-20145-01 g 524114 31 3,500 3,500 C 34-23 733-20041-00 W 524114 0 1,050 1,050 C 41-23 733-20163-00 ~ 524114 31 3,200 3,200 C 41-26 733-20409-01 W 524114 31 3,500 3,500 CASING PRESSURE 8. 9. MAX , Average PSIG PSIG DAILY AVERAGE INJECTION 10. 11. Liquid Gas (BBL) (MCF) TOTAL MONTHLY INJECTION 12. 13. Liquid Gas (BBL) (MCF) 100 67 ~ 80 46 334 3,300 3,250 581 120 63 1,243 95 48 1,330 24 20 196 170 107 (:.~0 100 86 0 3,475 3,451 104 3,500 3,069 731 1,050 1,050 0 0 0 2,450 0 0 157 27,404 10,349 18,024 38,547 41,219 21,085 0 3,209 22,661 0 4,837 ! hereby certify that the foregoing is true and correct to the best of my knowledge. $igned~ Title: Manager Ataska Operations Date: Total 269,245 Fom 10-406 Rev. 12-1-85 Submit in Duplicate LOTUS\MTHLYINJ\JULY-RPT.WK3 RECEIVED AUG 1 2 1991 AJaslm Oil & Cons. mmissien STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COHMISSION MONTHLY INJECTION REPORT 20 AAC 25.432 SHELL WESTERN E&P INC. Name of Operator MIDDLE GROUND SHOAL Field and Pool JULY, 1991 Month and Year of Injection TUBING PRESSURE 1. 2. 3. 4. 5. 6. 7. Welt # APl # CLass Field & Days in I~X Average 50- PoD[ Code Operation PSIG PSIG A 11-12 733-10083-00 W 524114 31 3,550 3'502 A 11-13 733-20007-01 W 524114 31 3,550 3,502 ___.__._A_j~2 733-20044-00 W 524114 31 3,550 3,502 A 23-01 733-20238-00 W 524114 31 3,550 3,502 A 33-14 7.53-20057-00 W 524114 31 3,550 3,502 A 34-11 733-10084-01 W 524114 31 4,400 4,348 A 34-14 733-10086-01 W 524114 31 3,550 3,500 · A 44-11 7.53-2002?-00 W 524114 0 N/A N/A C ?.~-26 7.53-20071-00 ~ 524114 31 3,500 3,500 C 24-?..3 733-20145-01 ~ 524114 31 3,500 3,500 C 34-23 733-20041-00 g 524114 0 1,050 1,050 C 41-23 7.53-20163-00 W 524114 31 3,200 '3,200 C 41-26 7.53-20409-01 ~ 524114 31 3,500 3,500 CASING PRESSURE MAX Average PSIG PSIG DAILYAVERAGE INJECTION 10. 11. Liquid Gas (BBL) (MCF) 100 67 884 80 46 334 3,300 3,250 581 120 63 1,243 95 48 1,330 24 20 196 170 107 680 100 86 0 3,4~5 3,451 104 3,500 3,069 7.51 1,050 1,050 0 0 0 2,450 0 0 157 TOTAL MONTHLY INJECTION 12. 13. Liquid Gas (BBL) (MCF) 27,404 10,349 18,024 38,547 41,219 6,066 21,085 0 3,209 22,~61 0 4,8,37 hereby certify that the foregoing is true and correct to the best of ny knowledge. Signed~ ' TitLe: Manager ALaska Operations Date: Total 269,245 Fona 10-406 Rev. 12-1-85 RECEIVED R/aBka 0il & 6as Cons. CommLsslen Submit in Duplicate LOTUS\MTHLYINJ\JULY-RPT.WK3 Shell Western E&P Inc.~ 601 West Fifth Avenue · Suite 800 Anchorage, Alaska 99501 June 14, 1991 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Gentlemen: SUBJECT: SUBMISSION OF THE APPLICATION FOR SUNDRY APPROVAL TO REPAIR TUBING/CASING ON MIDDLE GROUND SHOAL WELL NO. C24-23 Enclosed in triplicate is the application for sundry approval to repair tubing and casing on Well No. C24-23. The estimated date for commencing sundry operations is July 15, 1991. If you have any questions, please call Ms. Susan Murnan at (907) 263-9614 or Mr. Paul Huckabee at (907) 263-9646. Very Truly Yours, W. F. Simpson Manager Regulatory Affairs Alaska Division WFS/slm Enclosures R'ECEIVED JUN ~ 9199l' Alaska 011 & ~as Cons. Commission Anel~orage AOGCC\SUNDRY.DOC STA:I'E OF ALASKA ALAbr,~, OIL AND GAS CONSERVATION COMMISS,,JN APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon Alter casing __ Change approved program __ Pull tubing __ Operation shutdown Re-enter suspended well Plugging __ Time extension Stimulate Variance Perforate __ Other 6. Datum elevation (DF or KB3 2. Name of Operator Shell Western E&P Inc. 3. Address 601 West 5th Avenue, Suite 800 Anchorage, AK 99501 5. Type et Well: Development Exploratory Stratigraphic Service 4. Location of well at surface At top of productive interval At effective depth At total depth Suspend__ Repair Well X Platform C, Leg 4, Conductor 32. 541.65'N & 1596.41'W of SE corner of Sec.23, TSN, R13W, a.M. 426.5'N & 2507.86'E from SE corner of Sec.23, T8N, R13W, S. M. 581.59'N & 2418'E from SW corner of Sec. 23, T8N, R13W, S.M. 105' KB feet 7. Unit or Property name Middle Ground Shoal 8. Well number C24-23 9. Permit number 68-107 10. APl number 50-733-20145-01 11. Field/Pool MGS/"E", "F", and "G" Pools 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 9555' feet Plugs (measured) 9407' feet 9475' feet Junk (measured) 9328' feet Casing Length Size Structural Conductor Surface 1830' 10-3/4", 40.5#, J-55 Intermediate Production 9530' 7", 26 & 29#, N-80 Liner Cemented Measured depth True vertical depth 1300ax 1830' 960ax 9530' Perforation depth: measured 8108-9440' true vertical 7973-9294' Tubing (size, grade, and measured depth) (13 intervals) 4-1/2", 11.6#, N-80 Seal-lock at 7183' 3-1/2", 9.3#, N-80 EUE at 7183-8993' Packers and SSSV (type and measured depth) Guiberson RH-1 Packer @ 8076', 8272', 8799', 8896',8970'. 13. Attachments Description summary of proposal ~ Detailed operations program __ BOP sketch 14. Estimated date for commencing operation 07/15/91 115. Status of well classification as: I ........ ! Oil Gas Suspended 16. If proposal was verbally approved ~ -- ~ -- i .... I Service Injection Well ,o~ ~,~ame eT approver Date approved I ...... ~,~1,?. I hereby certify that the foregoing is true and correct to the best of my knowledge ~¥[''Signed ~, · ~-~o.,o-.~, ' ' Date //7/'7 ~/"~,,_ ~ Title ~A*'A c~ ~'~ '~ cAT°'"-~'r' ,~£P*/~ 6 / ! C,' ~ FOR COMMISSION USE ONLY -- 'Conditions of approval: Notify Commission so representative may witness Plug integrity._ BOP~es, t Location clearance Mechanical Integrity Teof~_ --Subsequent form require'--d 10- ORIGINAL SIGNE0 BY Approved by order of the Commission LONNIE C. SMITH IAppr°val N°' q/-_/~)C~7/ Commissioner Date Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE APPLICATION FOR SUNDRY APPROVALS DESCRIPTION SUMMARY OF PROPOSAL MIDDLE GROUND SHOAL WELL No. C24-23 REPAIR TUBING/CASING COMMUNICATION The Middle Ground Shoal well number C24-23 is known to have tubing/casing communication via observation of tubing/casing annulus pressure. The following operations are proposed to restore mechanical integrity in compliance with AOGCC Regulation 20 AAC 25.412 and Rule 6 of Area Injection Order No. 9. Attached is an illustration of the current and proposed wellbore diagrams. PROPOSED OPERATIONS SUMMARY 1) Shut-in well two to three weeks prior to workover to reduce required kill fluid density. 2) Cut tubing between each packer and above the top packer via wireline operations. 3) Kill well with Calcium Carbonate (CaCO3) mud. Estimated density is between 12.0 ppg and 15.0 ppg. 4) Pull tubing. 5) Fish and retrieve Guiberson RH-1 packer/isolation assemblies from 8076', 8272', 8799', 8896', and 8970'. A flat-bottom mill, junk baskets, and casing scraper will be run between each packer retrieval run to clean through perforation intervals. 6) Clean out wellbore to PBTD with bit and scraper. 7) RIH with test packer to 8000'(MD); 7864'(TVD) and pressure test casing to > 0.25*TVD = > 2000 psi. 8) Isolate "G" intervals from Hemlock by setting a Baker Model "DB" packer at 8500' MD (between the GR-GS and the HC-HD) and a Baker Model "DB" packer at 8000' MD (above the top GN-GO perforation). 9) Run 2-7/8" injection tubing and accessory equipment. 10) Replace wellhead components from seal flange up (including tubing hanger). 11) Displace CaCO3 mud with FIW. 12) Pressure test tubing/casing annulus to > 2000 psi (0.25*TVD). 13) Acid treat with 7-1/2% HCl to remove residual CaCO3 mud via Coiled Tubing Unit. 14.) Return to injection into the target HC - HZ Hemlock intervals. COMPLETION EQUIPMENT DETAIL SHEET MGS C24-23 7/20/87 NO. ITEM ,, 1. OTIS BALL VALVE NIPPLE 2. X-OVER 4 1/2" X 3 1/2" 3. OTIS "XO" SLIDING SLEEVE 4. OTIS "X" NIPPLE 5. GUIBERSON RH-1 PACKER 6. KBG MANDREL #1 APPROXIMATE TVD. MD. PSI OR 289 289 7053 7183 7900 8035 7934 8069 7941 8076 8095 8233 7. OTIS "XO" SLIDING SLEEVE(CLSD) 8130 8268 8. GUIBERSON RH-1 PACKER g. KBG MANDREL #2 10. OTIS "XO"'SLIDING SLEEVE 11. GUIBERSON RH-1 PACKER 12. KBG MANDREL #3 13. OTIS "XO" SLIDING SLEEVE 14. GUIBERSON RH-1 PACKER 15. KGB MANDREL #4 8134 8272 8616 8759 DUMMY 8652 8795 8656 8799 8713 8857 DUMMY 8748 8892 8752 8896 8788 8932 DUMMY 16. OTIS "XO" SLIDING SLEEVE(CLSD) 8823 8967 17. GUIBERSON RH-1 PACKER 8826 8970 18. OTIS "X" NIPPLE 8837 8981 19. OTIS "Q" NIPPLE 8848 8992 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 CASING 10 3/4", 40.5#, J-55 @ 1830' w/1300 sx 7" 26-29#, N-80 BUTTRESS @ 9530' w/960 sx PBTD = 9441' TD = 9555' TUBING 4 1/2", 11.6#, N-80 SEAL-LOCK @ 7183' 3 1/2", 9.3#, N-80 EUE @ 7183-8993' PERFORATED ZONE GROSS INTERVAL GN-GO GR-GS HC-HD HC-HD HD-HE HE-HF HI-HK HI-HK HK-HN HN-HR HN-HR HR-HZ HR-HZ 8108-8140' 8413-8466' 8702-8709' 8720-8758' 8766-8775' 8824-8865' 8928-8942' 8955-8967' 8985-9110' 9128-9185' 9198-9278' 9312-9333' 9355-9440 MGS C24-23 PROPOSED WELLBORE DIAGRAM - 6/14/91 XX XX / ,mw OTIS "X" Nipple @ 300' 24" Conductor Casing @ 370' 10-3/4" 40.5# J-55 @ 1830' 2-7/8" 6.5# L-80 EUE 8rd Tubing BAKER "CMF-D" Sliding Sleeve @ 7970' BAKER "DB" Pkr (anchored seals) @ 8000' GN-GO 8108-8140' MD 7972-8003' TVD X-over 7" 26#/29# N-80 @ 8370' GR-GS 8413-8466' MD 8273-8326' TVD BAKER "DB" Pkr (anchored seals) @ 8500' OTIS "XN" Profile Nipple @ 8530' BAKER Wireline Re-Entry Guide @ 8532' HC-HD 8702-8709' MD 8650-8567' TVD HC-HD 8720-8758' 8578-8615' HD-HE 8766-8775' 8623-8632' HE-HF 8824-8865' 8681-8721' HI-HK 8928-8942' 8784-8798' HI-HK 8955-8967' 8811-8823' HK-HN 8985-9110' 8841-8965' HN-HR 9128-9185' 8983-9040' HN-HR 9198-9278' 9053-9132' HR-HZ 9312-9333' 9166-9187' HR-HZ 9355-9440' 9209-9293' PBTD @ 9441' 7" 29# N-80 Production Liner @ 9530' TD @ 9555' PLATFORM "C" MIDDLE GROUND SHOAL CONDUCTOR/WELL SURFACE LOCATIONS LEG 1 Centered 541.65 ft. North and 1596.41 ft. of the SE Corner of Sec. 23, T8N, R13W, SM. CONDUCTOR WELL DISTANCE FROM SE CORNER NORTH WEST LEG 2 1 C23-23 547.10 1599.00 2 C32-23 547.25 1594.46 3 C34-26 544.25 1591.06 4 C24-26RD 540.57 1590.68 5 C31-26 536.91 1593.01 6 C34-23 535.88 1597.22 7 C23-26 538.03 1600.98 8 C22-26RD 542.18 1602.22 CONDUCTOR 9 10 11 12 13 14 15 16 LEG 3 LEG 4 CONDUCTOR 25 26 27 28 29 3O 31 32 Centered 618.65 ft. North and 1549.76 ft. of the SE Corner of Sec. 23, TSN, R13W, SM. DISTANCE FROM SE CORNER WELL NORTH WEST C22-23 623.65 1552.66 C24A-14 624.15 .1548.36 C43-i4 622.65 1544.76 C41-26 618.25 1543.86 C21-23 613.85 1546.26 C21-26 612.65 1550.46 -~4A-23 614.85 1554.26 C13-23 619.1.5 1555.66 Centered 582.42 ft. North and 1489.90 ft. of the SE Corner of Sec. 23, T8N, R13W, SM. Centered 505.41 ft. North and 1536.56 ft. of the SE Corner of Sec. 23, TSN, R13W, SM. WELL DISTANCE FROM SE CORNER NORTH WEST C42-23 C31-23 C43-23 C41-23 C33-26 C-LINE C44-14RD C24-23 509.00 1541.00 509.81 1536.57 507.65 1532.61 503.51 1531.56 499.00 1534.44 498.37 1538.72 500.87 1542.26 505.12 1543.10 West DISTANCE FROM CENTER OF LEG N/S E/W 5.45 -2.59 5.60 1.95 2.60 5.35 -1.08 5.73 -4.74 3.40 -5.77 -0.81 -3.62 -4.57 0.53 -5.81 West DISTANCE FROM CENTER OF LEG N/S E/W 5.00 -2.90 5.50 1.40 4.00 5.00 -O.4O 5.9O -4.80 3.50 -6.00 -0.70 -3.80 -4.50 ~0.50 -5.90 West West DISTANCE FROM CENTER OF LEG N/S E/W 3.59 -4.44 4.40 -0.01 2.24 3.95 -1.90 5.00 -6.41 2.12 -7.04 -2.16 -4.54 -5.70 -0.29 -6.54 PLAT fODld · IP%AYPOItd'T.~ · 8LUFIr L0~.AI'ION S.A.$. PL.ATFOAH ~'C" COOK INk. ET ."'-' ALASKA l~.4~( I% 2000' Mon~)l tNT WATER INJECTION REPORT PLATFORH C NOVEMBER *' C&l - 23 C24-23 C34- 23 C23-26 C41-26 INJ INJ AIdNU INJ INJ A#I~U INJ I#J AN#U INJ INJ ANNU INJ INJ AN#U DATE BBLS PRESS PSIG BBLS PRESS PSIG BBLS PRESS PSIG BBLS PRESS PSIG BBLS PREss PSIG 01-Nov-90 02-Nov-90 03-Nov-90 04-Nov-90 05-Nov-90 06-Nov-90 07-Nov-90 08-Nov-90 09-Nov-90 lO-Nov-90 11-Nov-90 12-Nov-90 13-Nov-90 14-Nov-90 15-Nov-90 16-Nov-90 1?-Nov-90" 18-Nov-90 19-Nov-90 20-Nov-90 21-Nov-90 22-Nov-90 23-Nov-90 24-Nov-90 25-Nov-90 26-Nov-90 2?'Nov-90 28-Nov-90 29-Nov-90 30-Nov-90 2539 3200 0 2568 3200 0 2556 3200 0 2581 3200 0 2565 3200 0 2548 32OO 0 2661 32OO 0 2552 3200 '0 2690 3200 0 2585 3200 0 2605 3200 · 2618 3200 0 2601 3200 0 2608 3200 0 2657 3200 0 258r 3200 0 2605 3200 .0 2636 3200 0 2623 3200 0 2595 3200 0 2601 3200 0 2625 32oo 262? 3200 0 2528 3200 0 2645 3200. 0 2598 3200 0 2654 32oo 0 2652 3200 0 2641 3200 0 2609 3200 0 3200 0 3200 0 MAXIMUMTOTAL 178,160 I 2605 AVERAGE# DAYS I 30 12/17/90 I 1027 3500 3500 1030 3500 3525 1031 3500 3525 1036 3500 3525 1031 3500 3525 1026 3500 3500 1028 3500 3525 1011 3500 3525 1015 3500 3500 1014 3500 3500 1024 3500 3500 1035 3500 3500 1027 3500 3500 1028 3500 3500 1090 3500 3000 1064 3500 3550 1058 3500 3550 1073 3600 3550 1070 3500 3550 1057 3500 3550 1064 3500 3550 1076 3500 3550 1076 3500 3550 1043 3500 3550 1070 3500 3550 1048 3500 3550 1069 3500 3550 1068 3500 3550 1060 3500 3550 1039 3500 3550 0 Sl 1250 0 Sl 1250 0 SI 1250 0 SI 1250 0 SI 1250 0 SI 1250 0 Sl 1250 0 Sl 1250 0 Sl 1250 0 Sl 1250 0 SI 1250 0 Sl 1250 0 SI 1250 0 Si 1250 0 Sl 1200 0 SI 1200 0 S1 1200 0 SI 1250 0 SI 1200 0 Sl 1200 0 Sl 1200 0 Si 1200 0 Sl 1200 0 SI 1200 0 Sl 1200 0 Sl 1200 0 Sl 1200 0 Si 1200 0 Sl 1200 0 SI' 1200 31,388 3600 3550 1046 3503 3513 ' 30 96 3500 34?5 102 3500 3450 102 3500 34?5 114 3500 3~25 110 3500 3425 110 3500 3425 111 3500 3425 109 3500 3425 109 3500 3~00 105 3500 3400 106 3500 3400 108 3500 3400 110 3500 3400 108 3500 3400 129 35OO 340O '123 3500 3410 0 3500 3410 238 3500 3400 124 3500 3410 124 35OO 3410 127 3500 3410 123 3500 3410 128 3500 3410 129 3500 3410 127 3500 3410 112 3500 3450 119 35OO 345O 125 3500 3450 127 3500 3450 118 3500 3450 494 3500 0 466 3500 0 453 3500 0 446 3500 0 435 3500 0 430 3500 0 424 3500 0 416 3500 0 416 3500 0 415 3500 0 414 35OO 0 413 3500 0 407 3500 0 406 3500 0 416 3500 0 409 3500 0 405 3500 0 408 3500 0 412 3500 0 406 3500 0 404 3500 0 399 3500 0 392 35OO 0 371 3500 0 378 3500 0 360 3500 0 369 3500 0 380 3500 0 386 35OO 0 381 3500 0 :0 0 0 0 30 1250 3500 34?5 3500 1225 116 3500 3422 410 3500 30 30 RECEIVED DE O 1 9 7990 Alaska Oil & Gas COos. Cofi3~JssJon Anchorage March-99 - WATER INJECTION REPORT PLATFORM C C41-23 J01-Mar-99 J 02-Mar-99 J 03 -Mar-99 J 04-Mar-99 05 -Mar-99 06-Mar-99 07-Mar-99 08-Mar-99 09-Mar-99 10-Mar-99 1 l-Mar-99 12-Mar-99 Mar-99 .,/Iar-99 15-Mar-99 16-Mar-99 17-Mar-99 18-M~-99 19-Mar-99 20-Mar-99 2 l-Mar-99 22-Mar-99 23-Mar-99 24-Mar-99 25-Mar-99 26-Mar-99 27-Mar-99 28-Mar-99 29-Mar-99 30-Mar-99 3 l-Mar-99 TOTAL MAXIMUM ~¥ERAGE ._.(" ')AYS ,. 08/99 ACT INJ INJ ANNU 1265 325O 3175 1306 3250 3175 1307 3250 3175 1320 3250 3150 1314 3250 3150 1316 3250 3150 1311 3250 3150 1298 3250 3150 1315 3250 3150 1296 3200 3150 1320 3250 3150 1310 3200 3150 1335 3200 3150 1327 3200 3150 1330 3200 3150 1329 3200 3150 1342 3200 3150 1333 3200 315C 1337 3200 315C 1333 3200 3150 1340 3200 3150 1358 3200 3150 1338 3200 3150 1339 3200 3150 1343 3200 3150 1354 3200 3150 1347 3200 3150 1357 3200 3150 1357 3200 3150 1366 3200 3150 1361 3200 3150 41,204 3,250 3,175 ACT INJ INJ ANNU 782 700 635 786 700 635 786 70O 635 792 700 640 793 70O 640 791 700 640 790 700 640 778 700 640 791 700 640 780 700 640 792 700 640 787 700 640 783 700 640 781 70O 640 782 700 640 787 700 640 790 700 640 789 700 640 790 700 640 779 700 640 783 700 640 793 700 640 789 700 640 788 700 64C 790 700 6401 792 700 6401 785 70O 6401 794 700 640: 792 700 640 794 700 64~ 792 700 641 24,421 700 640 C24-23 700 640 C34-23 C23-26 ACT INJ INJ ANNU C4 !-26 C24A-23 ACT [NJ INJ ANNU 1,329 3,216 3,152 788 31 31 381 3500 350¢ 1932 3500 391 3500 3500 1981 3500 391 3500 3500 1990 3500 395 3500 3500 2014 3400 393 3500 3500 2007 3400 392 3500 3500 2015 3400 394 3500 3500 2000 3400 392 3500 3500 2000 3400 396 3500 3500 2000 3400 390 3500 3500 2000 3500 395 3500 3500 2014 3400 395 3500 3500 2000 3500 404 3500 3500 2000 3500 400 3500 3500 2000 3500 401 3500 3500 2000 3500 399 3500 3500 2000 3500 402 3500 3500 2000 3500 399 3500 3500 2000 3500 399 3500 3500 2000 3500 396 3500 3500 2000 3500 397 3500 3500 2000 3200 403 3500 3500 2000 3200 396 3500 3500 2000 3200 396 3500 3500 2000 3200 397 3500 3500 1885 3200 400 3500 3500 1881 3200 397 3500 3500 1854 3200 401 3500 3500 1866 3200 399 3500 3500 1860 3200 401 3500 3500 1868 3200 398 3500 3500 12,290 61,021 3,500 3,500 3,500 0 396 3,500 3,500 1,968 3,371 0 31 31 ACT INJ INJ ANNU 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 1854 3200 0 ACT INJ INJ ANNU 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 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 0 0 0 0 0 0 0 0 0 550 425 0 550 425 0 550 425 0 550 425 0 550 425 0 550 425 0 550 425 0 550 425 0 550 425 0 550 475 0 550 425 0 550 475 0 550 475 0 550 475 0 550 475 0 550 475 0 550 475 0 550. 475 0 550 475 0 550 475 0 550 425 0 55O 425 0 550 425i 0 550 4251 0 550 425, 01 0 550 425 Oj 0 550 425j 0i 0 550 425i 0 550 4251 0 550 425 0 550 425 0 0 0 0 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 I 0 550 4751 0 550 0 550 441i 0 0 550 0 : 0 ACT INJ INJ ANNU C44-14RD ACT INJ INJ ANNU 798 3,500 26 2,134 6 57 3500 0 3500 0 3500 0 1600 0 1400 371 3500 176 3500 66 3500 74 3500 0 2100 0 1600 0 2100 0 2100 0 2100 0 2100 0 2100 0 1925 0 1925 54 3500 0 3500 0 3500 0 2800 0 1800 0 1800 0 350 0 650 0 640 0 600 0 525 0 475 0 475 February-99 01-Feb-99 02-Feb-99 03-Feb-99 04 -Feb-99 05-Feb-99 06-Feb-99 07-Feb-99 O8-Fcb-99 09-Feb-99 1 O-Feb-99 ! l-Feb-99 12-Feb-99 l~ 'b-99 1 ~-r¢~-99 16 -Feb-99 17-Feb-99 18-Feb-99 ' 19-Feb-99 20-Feb-99 2 i-Feb-99 22-Feb-99 23-Feb-99 24-Feb-99 25-Feb-99 26-Feb-99 27-Feb-99 28-Feb-99 TOTAL MAXIMUM AVERAGE ACT ACT INJ INJ ANNU 1NJ INJ ANNU 1290 3200 3110 1249 3200 311C 1243 3200 311C 1243 3200 311C 1235 3200 311C 1245 3200 3110 1264 3200 3175 1260 3200 3175 1273 3200 3200 1254 320O 32OO 1272 3200 3200 1269 3200 3200 1279 3200 3200 1286 3200 3200 1272 3200 3200 1275 3200 3200 1264 3250 3150 1248 3250 3175 1262 3250 3175 1243 3250 3175 1263 3250 3175 1251 3250 3175 1250 3250 3175 1257 3250 3175 1240 3250 3175 1224 3250 3175 1233 3250 3175 1292 3250 3175 35~36 3,250 3,200 1,258 3,221 3,167 28 795 700 630, 751 7O0 6301 751 700 630 75O 7O0 63O 751 700 630 751 700 630 754 700 630 753 700 630 821 700 630 747 700 630 757 700 630 752 70O 630 755 700 630 770 700 630 793 700 630 796 700 630 795 700 680 793 700 64O 799 700 640 785 700 635 $01 700 635 792 700 635 795 7O0 635 774 700 635 780 700 635 780 7OO 635 782 700 635 788 7O0 635 21,711 700 680 775 700 634 28 WATER INJECTION REPORT PLATFORM C C24-23 ACT C34-23 UI 1NJ INJ ANN 2151 - 3500 2121 3500 2114 3500 2104 3500 0 2082 3500 0 2095 3500 0 2126 3500 0 2119 3500 0 2313 3500 0 2094 3500 0 2118 3500 0 2106 3500 0 2104 3500 0 2O99 3500 0 2073 3500 0 2O46 350O 0 2091 3500 0 2086 .' 3500 0 2115 3500 0 2056 3500 0 2059 3500 0 1945 3500 0 1900 3500 0 1980 3500 0 1912 3500 0 1884 3500 0 1881 3500 0 1981 3500 0 C23-26 ACT INJ INJ ANNU ACT INJ INJ ANNU 438 3500 3500 401 3500 3500 399 3500 3500 396 3500 3500 394 3500 3500 397 3500 3500 399 3500 350O 398 3500 3500 433 3500 3500 392 3500 3500 396 35O0 3500 396 3500 3500 399 3500 3500 399 3500 3500 393 3500 3500 393 3500 3500 395 3500 35OO 392 3500 3500 396 3500 3500 395 3500 35OO 399 3500 35OO 399 3500 3500 400 3500 3500 402 3500 3500 386 3500 3500 367 3500 3500 370 3500 3500 393 3500 3500 11,117 3,500 3,500 397 3,500 3,500 28 57,755 3,500 0 2,063 3,500 0 28 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 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 0 0 0 0 0 0 0 C4 i-26 ACT INJ INJ ANNU 0 0 0 40C 0 0 0 40C 0 0 400 0 0 400 0 0 400 0 0 400 0 0 400 0 0 400 0 0 400 0 0 400 0 0 4O0 0 0 400 0 0 400 0 0 400 0 0 400 0 0 400 0 0 400 0 0 400 0 0 400 0 0 400 · 0 0 400 0 0 400 0 0 4OO 0 0 4OO 0 0 4OO 0 0 400 0 0 400 0 0 400 0 0 ' 0 400 0i 0 0 400 0 C44- ! 4RD i ACT INJ INJ ANNU 0 0 550] 0 0 5501 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0 0 550 0' 0 550 0 C24A-23 ACT INJ INJ ANNE 0 1400 366 1400 0 81 1400 0 21 3500 0 40 3500 0 24 350~ 0 13 3500 0 20 3500 0 20 3500 0 14 3500 0 8 3500 0 0 3500 0 0 3500 0 0 350O 0 0 35OO 0 373 3500 0 ! 20 3500 0 40 3500 0 12 3500 0 3 3500 0 0 3500 0 0 2200 0 0 1900 0 0 1850 '0 0 1600 0 0 ,1425 0 356 3500 0 147 3500 0 1,658 3,500 0 59 '2,971 0 17 Shell Western E&P Inc. 601 West Fifth Avenue · Suite 800 Anchorage, Alaska 99501 June 11, 1990 Alaska Oil and GaS Conservation Commission. ATTN: Elaine Johnson 3001 Porcupine Drive .Anchorage, Alaska 99501 SUBJECT' TRANSMITTAL OF REQUESTED INFORMATION REGARDING THE SWEPI OPERATED MIDDLE GROUND SHOAL FIELD Dear Ms. Johnson' In a recent telephone conversation you discussed with Ms. Susan Brown-Maunder information that would be helpful to you if we could provide it. Enclosed, for your convenience and use, are the following' location surveys showing the location of Platform A list of conductor/well locations (in relation to the SE corner of Sec. 11, TSN, R13W) for Platform A wells location survey showing the location of Platform C list of conductor/well locations (in relation to the SE corner of Sec. 23, TSN, R13W) for Platform C wells In addition you requested a revised copy of the Well Completion or Recompletion Report and Log (10-407) for the recently completed well C21-23. The well location at the top of the producing interval and the well location at total depth as been changed to reflect the actual surveyed location. If you have any further questions regarding these matters, please continue to contact Susan Brown-Maunder at (907) 263-9613. Very Truly/Yours, W. F. Simpson Manager, Regulatory Affairs Alaska Division WFS/SBBM/vj Enclosures cc' Susan Elsenbast-AOGCC \LETTERS\AOGCC\061190. DOC RECEIVED JUN 1 Oil.& Gas Cons. Comml,~l~rl Anchora~ May 5, 1989 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Shell Western E&P Inc. .2 601 West Fifth Avenue- Suite 810, ~ I~_~_~_~.-M]_T~__ ~"~ ~ C~ ~ ' ~ '~ ...... ~'F~'e F- ib. ...... A~.~ Gentlemen: SUBJECT: AREA INJECTION ORDER NO. 9 (CENTRAL PORTION MIDDLE GROUND SHOAL FIELD), RULE 6 As part of the requirements of Area Injection Order (AID) No. 9, Rule 6, a schedule for performing radioactive tracer surveys (RTS) must be submitted to and approved by the commission. During conversations with members of your staff it was indicated that the Commission may accept recent RTS's even though the commission representatives did not have the opportunity to witness the surveys. By way of this letter, SWEPI is submitting our schedule for performing RTS's on injection wells and request that you accept the recent surveys as satisfying the requirements of Rule 6 based on the enclosed RTS logs. (See Attachment 1 for list of enclosed logs.) Attachment 2 is a table showing the mechanical integrity history for the MGS in,iection wells. Also shown is the proposed testing schedule noting those wells for which we are asking your acceptance o~= the previously run surve.ys. · Your early review of this proposal would be greatly appreciated. If we can be of further assistance, please do not hesitate to call Ms. Susan Brown-Maunder at (907) 263-9613. Very truly yours, W. F. Simpson Manager Regulatory Affairs SBBM/hr Enclosures Gas ConS. Comm'~ssloa GTK1/050489 Attachment 2 MGS WATER INJECTION WELL MECHANICAL INTEGRITY HISTORY Most TBG/CSG Most Recent Recent Well No. Con~nunication Pressure Test RTS Method For Future Test Proposed Da te For Next Test All-12 Yes~ N/A 6/87 (1) All-13 RD II Yes v · 2/26/87 1/86 A12-12 Yes ~ N/A 3/88 (l) A23-01 RD No v 11/3/88 - A33-14 No ~ Failed 2/26/87 3/88 (1) A34-11 No ~ 11/3/88 - A34-14 RD II No % Failed 2/26/87 6/87 A44-11 Yes / N/A 3/88 RTS RTS RTS Pressure Test RTS Pressure Test RTS RTS 6/89 2) e/89 2) 3/90 3) 11/92 3/90 (3) 11/92 6/91 C23-26 Yes ~. 12/86 1/87 C24-23 ~ Yes -' N/A 2/87 C34-23 -~ Yes N/A 1/87 (1) ~41-23 No N/A 10/87 (1) C Line Well Shut-ln Shut-ln Shut-ln RTS 6/89 RTS 6/89 RTS 6/89 RTS 10/91 (3) N/A - (1) AOGCC did not witness survey. (2) Delay due to unavailability of large crane. (3) Schedule subject to approval of AOGCC. Nomenclature: RTS - Radioactive Tracer Survey GTK1/050489 ¢24'.23 '~ C34-.23 r C, 41-33 RAr. 6117187 ~rL 1117/86 NfL 314/88 t'IFL. 315188 RA?' 6117187 NFL .. 9/5186 RT$. 3/26/88 t, IFt. 112.6187 t, IFL 2.112187 t, IFL. 1127/87 t, IFL 2110/87 ~FL . 2./12./87 NFL. 10/24/87 RECEIVED MAY - 5 1989 A~ka Oil & Gas Cons. Commission Anchorage GTK1/050489 RE RETAIN THIS SECTION~OR-YOUR,RECORDS ~ COMP, NFL-TEMP. OFfs, 2/10& i ~.'~ ~'~ C23-26(NFL) ~C24-23(NFL) ~,,N~ _L~~/217/87~ tPll- L OE~,Z/.12/U7),~ ALL PLS'S PRINTS NEG. ~ SEPIA PRINTS 0 NEG. ~, SEPIA PRINTS NEG. SEPIA PRINTS NEG. SEPIA PRINTS NEG. SEPIA PRINTS NEG. SEPIA PRINTS NEG. ....... ~_ SF=P~A ATTENTION JOHN BOYLE SIGNED Alaska oil aD,~I~E Cons, Commiss~io119 ,.. Anchorage STATE OF ALASKA :"~ ALASK. ,OIL AND GAS CONSERVATION COME. ~SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order [] Perforate [] Other)~] 2. Name of Operator 5. Datum elevation (DF or KB) SHELL WESTERN E&P INC. 105' 3. Address 6. Unit or Property name 601 West Fifth Avenue, Suite 810, Anchorage, Alaska 99501 Middle Ground Shoal 4. Location of well at surface Platform IICII, Leg 4, Conductor 32. 541.65' N & 1596.41 ' W of SE corner of Sec. 23, T8N, R13W., S,M. At top of productive interval 426.5'N & 2507.86'E from SE corner of Sec. 23, TSN, R13W At effective depth At total depth 581.59'N & 2418'E from ~ comer of Sec. 23, T8N, R13W, S.M. 7. Well number C 24-23 8. Permit number 68-107 9. APl number 50- 733-20145-01 10. Pool "E" & "G" Pools 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 9555' feet Plugs (measured) 9407' feet 9475' feet Junk (measured) 9328' feet Casing Length Structural Conductor Surface 1830' Intermediate Production 9530' Liner Perforation depth: measured true vertical Size Cemented Measured depth True Vertical depth 10-3/4", 40.5#, J-55, 1300 sx 1830' 7", 26 & 29#, N-80 960 sx 9530' 8108- 9440 ' 7973-9294' (13 intervals) Tubing (size, grade and measured depth) 3-1/2" & 4-1/2" Packers and SSSV (type and measured depth) packer @ 7999' , , set @ 8065' 12.Attachments Description summary of proposal ~ Detailed operations program [] BOP sketch [] 13. Estimated date for commencing operation 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that .the foregoing is true and correct to the best of my knowledge Signed ~,//~ r ',~-¢,,~,,~.~ Title Production Superintendent Commission Use Only Date 12/8/86 Conditions of approval Notify commission so representative may witness I pprova, No. [] Plug integrity [] BOP Test [] Location clearance RAT tests to be run in 1987 to demonstrate no fluid movement behind tubing above the top packer; at least one shot (in each well) to demonstrate ability to see fluid movement behind t~byinm. oE:f~r of · "~' ~;~;m-;:',~-<~,,~ (.>6ommissioner the commission Date ~ ' Approved by ~;~ ~ ~ ~ ~;'~ ~ ~ '~ ~ ~ j ~ ~ r - ~ ~h ' Form 10-403 Rev 124-85 ~ ,.,~'?'¢ ~ ;~;:~,~i~ /.~_/~;. Submit in triplicate ATTACHMENT TO APPLICATION FOR SUNDRY APPROVAL This Application for Sundry Approval is being submitted to present to the Commission Shell Western E&P Inc.'s surveillance plan to insure integrity of wells which indicate communication between the tubing and the tubing/casing annulus by elevated pressure in the annulus. The surveillance plan will use periodic (two to three year cycle) radioactive tracer surveys to determine if there is any fluid movement behind the tubing above the packer in the tubing/casing annulus. Between surveys annulus pressure and injection flowrate will be monitored. These values are reported to the Commission monthly. If, for uneXplainable reasons, the flowrate increases by 25% or more, or the annulus pressure increases by 200 pounds or more, a radioactive tracer survey will be run to determine if there is flow in the annulus. This procedure will insure that no significant amount of water is injected outside of the waterflood interval. As all aquifers beneath the Middle Ground Shoal field are exempt aquifers, there is no threat to drinking water in the unlikely chance that an injection water leak should occur. 1211/MISC December 17, 1985 Shell Western E&P Inc. 601 West Fifth Avenue * Suite 810 Anchorage, Alaska 99501 State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99502 SUBJECT- OCTOBER MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS Gen tl emen' Please find the enclosed monthly reports of Drilling and Workover Oper- ations for our Middle Ground Shoal wells. The three wells that were worked on during the month of October were.A22-14, C24-23 and C22-26RD. Each enclosed monthly report is submitted in duplicate. V~'~trul y yours, Sr. S~ff Environmental Engineer Alask~ Division SBB/kka Enclosures RECEIVED '~-~o~a., ,~, .. Oil & Gas Cons. CommissJOrl SBBB/aogcc. 2a STATE OF ALASKA ,--~ 'ALASKA~ ~AN~D GAS CONSERVATION CC ~ISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS · Drilling well [] W0rkover operation 2. Name of operator She1! Western E & P Inc. 3. Address 601 West Fifth Avenue, Suite 810; Anchorage, AK 99501 4. Location of Well atsurface Conductor 32, Leg 4 @ 36.53'S & 53.31'E of center !eg 1. 541,65'N & 1596.41'W of SE corner of Sec.23, T8N, R13W, S.M. 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 116' KB ADL !8756 7. Permit No. 68-107 8. APl Number s0- 733-20145-01 9. Unit or Lease Name Middle Ground Shoal 10. Well No. C 24-23 11. Field and Pool Middle Ground Shoal "G" Pool For the Month of ,19 RE ~12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks N/A 13. Casing or liner run and quantities of ceme'nt, results of pressur9 tests NONE 14. Coring resume and brief description NONE 15. Logs run and depth where run NONE DST data, perforating data, shows of 1-12S, miscellaneous data See attached worksheet for details. RECEIVED 41aska Oil & Gas Cons. Commission Anchorage 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SIGNE~ ,~--~~TJTLE Production Superintendent DATE ~,_, NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate WORKSHEET FOR MIDDLE GROUND SHOAL C 24-23 Date Started: Date Completed: ~o/~4/85 ~o/~5/85 Operation: Acidization Procedure: 1. Rigged up coiled tubing unit and Dowell. 2. Pressure tested Dowell to 5000ps1 and tested coiled tubing unit to 3500 psi. Ran in hole with colled tubing unit (CTU). Bled pressure off the coiled tubing and it collapsed. Successfully packed off around collapsed coiled tubing. Pulled collapsed tubing out of hole and shut well in. Pressure tested and ran in hole with 3000 psi in coiled tubing. 7. Displaced injection water with 2000 gal of acid over the HR/HZ and 2000 gal of acid over HN/HR. 8. Displaced acid with injection water. 9. Cleaned out rat hole. 10. Rigged down CTU and placed well back on injection. . . RECEIVED Ah~ska Oil & ~as Corls. Cnmrnin~ior~ Anch,~ ...... ,. December 17, 1985 Shell Western E&P Inc. 601 West Fifth Avenue * Suite 810 AnchoraGe, Alaska 99501 State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99502 Gentlemen: SUBJECT: SUBSEQUENT REPORT FOR MIDDLE GROUND SHOAL WELL C24-23 Enclosed are duplicates of the Subsequent Report for the recently completed acidization of the Middle Ground Shoal well C24-23. If you need additional reports or information, please contact Susan Brown at (907) 263-9613. Sr. '~fl ~dvi ronm/ental Engineer Alaska Division DLY/kka Enclosure RECEIVED o~'C 2 o Alaska Oil & Gas Cons, CommJss/or~ Anchorage SBBC/aogcc.4b STATE OF ALASKA ALASK~(~)IL AND GAS CONSERVATION" ~MMISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL COMPLETED WELL OTHER [] 2. Name of Operator 7. Permit No. Shell Western E & P Inc. 68-107 3. AddreIs 8. APl Number 601 West Fifth Avenue, Suite 810; Anchorage, AK 99501 5o-733-20145-01 4. Location of Well Conductor 32, Leg 4 @ 36.53'5 & 53.31'E of center leg 1. 541.65'N & 1596.41'W of SE corner of Sec. 23, T8N, R13W, S.M. 5. Elevation in feet (indicate KB, DF, etc.) 116'KB 12. I6. Lease Designation and Serial No. ADL 18756 9. Unit or Lease Name Middle Ground Shoal 10. Well Number C 24-23 11. Field and Pool Middle Ground Shoal "G" Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEOUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing Stimulate r-J Abandon Itl Stimulation J~] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing r-J Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13, Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Please see attached worksheet for the details of the completed work. RECEIVED Oil & Gas Cons. Commission Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. S,.----~ ~ ,g,e~ ,----~,..~ ~ .~. Pnoduction Superintendent The space below for Commission use Date -/ Conditions of Approval, if any: By Order of Approved by. COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate WORKSHEET FOR MIDDLE 6ROUND SHOAL C 24-23 Date Started: Date Completed: 10/14/85 10/15/85 Operation: Acidization Procedure: 1. Rigged up coiled tubing unit and Dowell. 2. Pressure tested Dowell to 5000psi and tested coiled tubing unit to 3500 psi. 3. Ran in hole with coiled tubing unit (CTU). 4. Bled pressUre off the coiled tubing and it collapsed. Successfully packed off around collapsed celled tubing. 5. Pulled collapsed tubing out of hole and shut well in. 6. Pressure tested and ran in hole with 3000 psi in coiled tubing. 7. Displaced injection water with 2000 gal of acid over the HR/HZ and 2000 gal of acid over HN/HR. 8. Displaced acid with injection water. 9. Cleaned out rat hole. 10. Rigged down CTU and placed well back on Injection. RECEIVED Alaska Oil & Gas Cor~s. Commission Anchorage October 10, 1985 Shell Western E&P Inc. 601 West Fifth Avenue · Suite 810 Anchorage, Alaska 99501 State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Gentlemen: SUBJECT: PROPOSED WORKOVER FOR MIDDLE GROUND SHOAL WELL NO. C 24-23 The enclosed Sundry Notice for Middle Ground Shoal informs you of our intentions to perform an acidization of the subject well. The work is scheduled to begin on October 14, 1985. The notice is submitted in triplicate If there are further questions, please contact me at (907) 263-9613. SBB/kka Very truly yours, Susan Brown SEC Group Alaska Division Enclosure SBBB/aogcc.2 STATE Of ALASKA ~'":' ALASKA (all AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator Shell Western E & P Inc. 3. Address 601 West Fifth Avenue, Suite 810; Anchorage, AK 99501 4. Location of Well Conductor 32 of Leg 4. 541.65'N & 1596.41'W of SE Corner of Sec. 23, Twsp 8N, Rge 12W. S.M. 5. Elevalisl~i~l[~:et (indicate KB, DF, etc.) 6. Lease Designation and Serial No. ADL 18756 7. Permit No. 68-107 8. APl Number 50- 733-20145-01 9. Unit or Lease Name Mi dd ! e Ground Shoal 10. Well Number C 24-23 11. Field and Pool Midd!e Ground Sh0a! "G" PO01 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [~ Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] [] Other [] Pulling Tubing [] Pull Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Please see the attached prognosis for details of the acid job. Note that the work is scheduled to begin on October 14, 1985. 2ECEIvED OC? 1. 0 4laska &AGn"aS'cnorageC°ns' C°rnm/$sloa 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~,,,~,[~,1~ TitlePrOdUCti 0n Engineer The spaceqSelow for Commission use Date0ctober 10, 1985 Conditions of Approval, if any: IRISlll,IL SIGNED 8t' LBHI~IE C. SMITH Approved by. COMMISSION ER ~pprovea Copy Retyrnec~ By Order of the Commission Date / __~L./__/]~___~. ..... Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate Form 10-403 Rev. 7-1 ~0 P. CIDIZ£ HITH COILED TU~II~ C~4-~3 MIDDL~ 6ROU~D ~lqL-FI£LD STATUS; Currently injecting 17~)0 BOW at 3500 psi into the GR/GS~ HC/HD, HI/HKe HK/HN &nd HR/HZ zones. MECHANICAL DETAILS: See attached schematic OBJECTIVE: Increase inJection by stimulating lower Hemlock zones HN/HR and HR/HZ. NOTEI SWS RAT survey tagged fill at 9395' PROCEDURE: 1. Rig up slickline. Test lubeicator to 3500 psi. Make drift run to bottom (9~,1'). Tag and record fill. POOH and rig down. Rig up coiled tubing and acidizing equipment, Test li~es, tree end CTU to 58~0 psi. Test acid for strength by titration and hydrometer. This operation is to be ~itnessed by · Shell rep- resentative, Test hydraulic system and BOO. 3. With well shut in RIH with CTU to 9~e~ #bile injecting filtered seawater through coiled tubing. 4~00 gal, 15~ HCL will be pumped. The only additive to be used is 1~ DowelI R2~ lr~ibitor, NOTEI All acids and fluids a~e to be tested for coep&tibility with injection wate~ prior to t~eatment, ~lso, an irLlection rate of ! bbl/~in Ihould be used but an injection pressure of 8~ psi is r~t to be exceeded. Begin injecting filtered seawter in the coiled tubing-tubing annulus at a ~ate of L:5~ BPD. Beginning at 9~45' puep.the following tree:cents filtering all fluids through a ~ ~tc~o~ filterl STAGE aCID VOLUME INTERVAL ZONE I 15~4CL ~e00 ~ 944~-93]~' HR/HZ ~ 15~HCL ~ ~ 9~78-91~8' HN/HR 7, Displace acid out of coiled tubing with 11 bbls of i~jection water. Flush v~laining aci~ with an additional ~ bbl~ of injection water. POOH with CTU. 8. Place well on injection. Rig do~n coiled tubing and acid equipment, Send results to S. M. Logan, Houston, Woodcreek ~'~'^'/~I~ 1139, ,xtenslon **~$. 09:16 M , rLS e. ".D. 1. 8~33' Z. 8759' Dummy 3. 8857' DunKy 4. 8932' Dummy ~" 0-1830' 7" N-80 Buttress 26# 0-8070' 291 8070.9530' NOTE: 18' pup LB 8680' TUBING ~ 11,$t 1t-80 Seal-Lock (2ZO ~T) 0-7183' 3 1/Z' 9.39 N-80 £U£ (SSJT) 7183-8993' PERFS ~140' 6N-GO 8413-8466' GR-G5 8702-8709' 8720-8758' 8766-8775 HC-HD 8824-8865' HE-HF 8928-8942' 8956-8967' HZ-HK 8985-9110' HK-HN 9125-9185 ' 9198-9278' HH-HR 9312-9333' 9355-9440' HR-HZ Bill Valve e Z89' XO Sleeve LB 8035' X-Htpple LB 8069' RH-1 Packer LB 6076 KBG J1 LB 8233' Pulled dummy 8-28-81 Pocket open to GN-GO xo si eeve LB 8268' closed RH-1 Packer 9 8272' KBG #2 LB 8759' Dummy XO Sleeve LB 8795' Open 6-9-77 RH-1 Packer LB 8799' KBG #3 LB 8857' Dummy XO Sleeve e 8892' Open 6-9-77 RH-1 Packer LB 8896' KGB f4 LB 8932' Dummy XO Sleeve LB 8967' Closed RH-1 Packer 9 8970' X Ntpple 9 8981' iQ Ntpple ~ 8992' SCHLUMBERGER OFFSHORE SERVICF'$ A Division of Schlumberger Limited HouSTON. TEXAS 77001 .. SEPTEMBER ':19,1985 ,.-,rA.- .[PLY TO ANCHORAGE, ALASKA 99518 ATTN' BETH CUZZORT SHELL WESTERN E&P INC. P.O. BOX 527 HOUSTON, TX. 77001 Attention: LOG FILES, WCK 4147 Gentlemen: Enclosed are lBL .prints of the pRODUCTION LOG Company SHELL WESTERN E&P INC. ,Well MGS C 24-23 Field MIDDLE GROUND SHOAL Additional prints are being sent to: 1BL nrints SHELL WESTERN E&P INC. P.O. BOX 527 HOUSTON, TX. 77001 ATTN' R.J.VALLEJO ,WCK 1134 2BL orints SHELL WESTERN E&P INC. uul W.FIFTH AVE;SUITE 810 ANCHORAGE, ALASKA 99501 ._ ATTN' JOE FRAM 1MYLAR 1BL nrints ARCO ALASKA INC. P.O. BOX 100360 ANCHORAGE, ALASKA 99501 ATTN: JOHN C. HAVARD on: , ,Coun~ KENAI S~te, ALASKA / STAT~--OF'"ALASKA '~'5 ~ ALASKA Oil, & GAS CONSERV~TION,,.~. ONN. k 3001 PORCUPINE DR. ~ .... ~,. ANCHORAGE, ALASKA _~9-~3'~ :i" .'' . o: 1BL nrints SHELLrPLATFORM "A" OR "C" C/O SHELL KENAI OFFICE NORTH STAR ROUTE #1 P.O. BOX 485 WIK RD. KENAI, ALASKA 99611 ~prints 1RROLLED SEPIA ~~;[r~r~s U.S.A. ,INC. P.O. BOX 107839 ANCHORAGE, ALASKA 99510 ATTN' J.L. WEAVER prints SO~'-1565-A The film is RETURNED TO SHELL , ( HOUSTON ) We appreciate the privilege of serving you. RECEIVED BY'~D r-/~ · / " Vew truly yours, Anchorage' Sion SCHLUMBERGER OFFSHORE SERVICES DISTRICT MANA~WR November 3, 1983 Shell Oil Company 200 North Dairy Ashford P. O. Box 527 Houston, TX 77001 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Gentlemen- Attached are duplicate copies of the Monthly Report of Drilling and Workover Operations for Shell's Middle Ground Shoal Well A12A-1 and Seal Island Well No. BF-47. Also attached are duplicate copies of Subsequent Sundry Notices for Workover Operations for Shell's MGS Wells C31-23, C34-23, C31-26 and Yours very truly, R. G. Hollis Manager Production Administration Pacific Frontier Division RGH:mh Attachment STATE OF ALASKA ALASKA OI'L AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL (~X OTHER [] 2. Name of Op_erator 7. Permit No. She]] 0il Company 68-107 3. Address 8. APl Number John Douglas, P.O. Box 4500, Kenai, AK 99611 5o-733-20145-01 4. Location of Well Conductor 32, Leg 4 @ 36.53' S and 53.31' E from the Center of Leg 1 which is at 541.65''N and 1596.41' N from the SE Corner of Sec. 23, T8N, RI2N, S.M. 5. Elevation in feet (indicate KB, DF, etc.) 105' D.F. 12. 6. Lease Designation and Serial No. ADL 18756 9. Unit or Lease Name MGS 10. Well Number C 24-23 11. Field and Pool Middle Ground Shoal "G" Pool Check Appropriate Box To Indicate Nature of Notice, RepOrt, or Other Data NOTICE OF INTENTION TO' SUBSEQUENT REPORT OF: (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) (Submit in Duplicate) [] Altering Casing [] X~ Abandonment [] [] Other [] 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). PROPOSAL- Aci dize with Coil ed Tubing 10/24/83 - Rigged up Otis and Dowell. Pressure tested to 5000 psig. RIH Pumped 500 Gal. 10% HCL from 8992' to 9440'. Pumped 2100 Gal. 10-12% HCL/HF across perfs. Pumped 500 gal. 10% HCL across perfs. Displaced coiled tubing. POOH and Rigged down. _~o~ 14. I hereby pe~tify that the ~/oregoing is true and cbrrect to the best of my knowledge. Signed : Title PrOdUCtion Adm. Manager The space below for Commission use Date 11/3/83 Conditions of Approval, if any: By Order of Approved bY. COMMISSIONER the Commission Date Form 10~,03 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate STATE OF ALASKA ALASKA OiL AND GAS CONSERVATION CO,wMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WE LI-~ OTHER [] 2. Name of Operator 7. Permit Shell 0il Company 68-:107 3. Address 8. APl Number John. Douglas, P.O. Box 4500, Kenai, AK 99611 5o_733-20145-01 4. Location of Well Conductor 32, Leg 4 @ 36.53' S & 53.31' E from'the Center of Leg I which is at 541.65' N & 1596.41' W from the 9. Unit or Lease Name HGS 10. Well Number C 24-23 SE Corner of Sec. 23, T8N, R12W S.M. 5. Elevation in feet (indicate KB, DF, etC.) 105' D.F. 12. I 6 . Lease Designation and Serial No. ADL 18756 11. Field and Pool Middle Ground Shoal "G" Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO; SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent, details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ' ~ ~ Proposal- Determine injection profile. 10/13/83 - Rigged up Dresser Atlas. Ran spinner and radioactive tracer injection survey. 10/14/83 - Completed survey. R,D. 14. I hereby certify that the foregoing is true and correct to the best of my knowledge, The space below for Commission use Date 10/,27/83 Conditions of Approval, if any: By Order of Approved by. COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate STATE OF ALASKA ALASKA O~L AND GAS CONSERVATION COivfMISSlON SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL r--1 2. Name of Operator Shell Oil Company, 3. Address John Douglas,, P.O, Box 4500, Keani, AY,' COMPLETED WELL OTHER [] 99611 4. Location of Well Conductor 32, Leg 4 @ 36.53~ South and 53.31'~' East from the center of Leg 1 which is at 541.65~ North. and 1596.41" West from the Southeast Corner of Sec. 23, T8N, R12W, S.M. 5. Elevation in feet (indicate KB, DF, etc.) 105t D.F. 6. Lease Designation and Serial No. ADL 18756 7. Permit No. 68-107 8. APl Number 50- 733-20145-01 9. Unit or Lease Name MGS 10. Well Number c 24-23 11. Field and Pool Middle Ground Shoal "G" Pool 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Stimulate ~ Abandon [] Stimulation [] Repair Well [] Change Plans [] Repairs Made [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion,) Altering Casing Abandonment Other [] [] [] 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Please see attached. Alaska 0il & Gas Cons. Commission Anchorage 14. I hereby certj,f~that.the fpr~going is true and correct to the best of my knowledge. Signed ~/~_ ~ /~~ Title Mgr. Prod. Admn. Date 9/30/83 The space below for Commission use Conditions of Approval, if any: ORIG;NAL SIGNt:D BT LONNIE C. SMITil Ap.~r~ Cop~ ~eturned By Order of COMMISSIONER the Commission Approved by. Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate H'b ~-'~ ~,~,-'7- A- ,AUTHQRI,'i'Y FOR EXPENDITURP-',, ~ '--DEPT. '" ' [ 8RANO. t QI=FIC~' '} ORI~iNA'I:ING 0FFIC~ ,~.F.F.. NO. .-' PRODU~ION PACIFIC DIVISION ........... HOU~ON "'L~~ OF ~~ ~RIA~ C24-23 Niddle G~ound Shoal 'Fie~d 9/22/83 Kenai, AK ' LO:ATIOH HO~BER ~RK m m m mm ~HELL'~ ~ ~HARE . ORDER ~PE OE~I~ION .... NUM~E~ 1~ ~ ~u~ N~.eU~ m mm m m mm m R&R Acidize C24-23 using co~]ed $32,000 $]0,700 $]0,700 tubing Non 0pera~o?s Approval Not Requi red Requested b~' a. H. Doug]as T. S. Burns ~Um--~O~A~ $32,000 $]0,700 $]0,700 m m mm m BUDGe' AVAILAOLE IN BUDGET , , iRE~iREMCNT ,,~°~'"°".., , .~ c..,... ~..o..~o.,.~o, , , 0~ .~o.., ..~,~,o., ,.o... :o..,. ., - ~] ~ ~ 7oo JUSTIFICATION: 'See ~ached justification. . , ., RECEIVED OCT ! Alaska Oil & Gas Cons. Commission ' ' Anchoraoe , OV~ RECOMMENDED APPROVALS m m m m . , , , Justification Acidize with Coiled Tubing C24-23 -~ Middle Ground Shoal Field Funds totalling $32,000 ($10,700 Shell's 1/3 share) are requested to acidize C24-23, Platform "C", Middle Ground Shoal Field, Cook Inlet, Alaska. The economics are as fOllows- Shel 1 Net Total Gross Expend i ture $10,700 $32,000 Injection Increase BDW 100 300 Oil Response BDO 12 37 P.V.P.A.T. @ 14% 21,355 64,065 % P.V.P.A.T. 200 200 Pay Out 3 3 Well C24-23 was drilled and completed in December 1968. In 1969, well C24-23 was converted to injection with an initial rate of 2900 BDW. In 1972, the well was pulled and the HI/HK was isolated with packers. After declining to 1200 BDW in 1982, the well was acidized using coiled tubing. A total of 2500 gallons of HC1 and mud acid was placed across the HK/HZ perforations. Injection increased to 1900 BDW for 8 months as a result of the acid job. The injection rate has since declined to a rate of 1600 BDW. An offset producer (C43-23) was recently reperforated (Dec. 1982) in the HK/HN(L). Oil production increased approximately 300 BDO, but declined at 55% per year. Subsequent acid and reperforating jobs proved uneffective. It appears that the HK/HN(L) zone lacks pressure 'support in this area. Stimulation of C24-23 in this zone would improve the situation.. In August 1983, C43-23 had further water breakthrough in one ot its producing members. Injection surveys are planned in the offset injectors to possibly determine which well contributed to the breakthrough. Acidizing C24-23 is contingent on the results of the s u rvey ~ Both C24-23 and C23-26 were acidized along with C34-23 in the spring ~ 1982 program. Initial injection increase from the program was 2650, bu~ quickly stabilized at an increase of 1800 BDW. Four producers in ~ Pattern 5 and 6 responded to the increased injection. In oil increa.s~ of 240 BDO over the previous decline was noted. An 8 to i ratio of~ ~ incremental injection to production was established.® Since August, 1982, Platform "C" has experienced a fuel gas shortage. Frequent water flood shutdowns have occurred as a result of the fuel gas~ shortage. During the shutdown periods, the conditions were favorable for bacteria growth in the water injector's wellbore. It is believed that a combination of bacteria and scale have clogged the perforations resulting in the decline in injection. An acid treatment will kill and dissolve the bacteria along with dissolving scale and clay fines. If this treatment is successful, a study will be undertaken to determine the extent of bacteria perforation plugging and the feasibility of a continuous biocide injection system to eliminate bacteria growth in the we 11 bo re. Acidizing C24-23 in the lower zones should increase the injection rate back to the 1900 BDW. This 300 BDW increase in injection should increase production in the neighboring wells by 37 BDO. The increase is assumed to have a 50%/year decline rate over a 12-month period. Your approval is reCommended. TSB'mh Alaske Oil & Gas Cons. Anchorage, Prognosis Acidize with Coiled Tubing C24-23 W. H. Room #1 Conductor 6 Middle Ground Shoal Field Status: Well currently injection 1600 BDW at 3500 psi. Objective: Increase injection by removing scale and bacteria which may have formed in the last 18 months. Procedure: I Rig up wireline and test lubricator to 3000 psi. Make drift run to bottom. Tag and record bottom. P.O.O.H. and rig down. . Rig up coiled tubing and acidizing equipment. Test acid according to attached quality control procedure. Filter all fluids on the fly through a 2 micron filter. Test all lines and coiled tubing to 5000 ps i. I With well shut in, R.I.H. with coiled tubing to 9440' while pumping inlet injection water. With coiled tubing at 9440', pump the following treatments: Stage Acid Volume 10% HC1 700 gal. (17 Bbls) 12%-10% HCl-HF 2100 gal. (50 Bbls) 10% HC1 700 gal. (17 Bbls) (Acid additives are listed on attached information sheet) Reciprocate pipe across perforated interval (9440'-8992') during each stage of acid treatment. . Displace acid to end of coiled tubing using filtered injection water. Pump an additional 10 Bbls injection water to flush coil. P.O.O. H . with coiled tubing, i~,~<.~' ~"~L!~ ~ L~ ,o 5, Place well on injection. Rig down coiled tubing and acid equipment. Send results to T. S. Burns, Houston. T SB 'mh'~ la/%/~7 ~4~ ~[~ Appro~ Date Well History C24-23 Middle Ground Shoal Field November 1968 December 1968 July 1969 February 1971 August 1971 August 1971 July 1972 September 1972 May 1976 January 1979 Apri 1 1982 Spudded Completed Converted to injection Pressure Falloff Survey Pump bacteria destruct and acid down tubing R.A.T. Survey Pulled well, acidized, reran tubing wi th isolation packers R.A.T. Survey R.A.T. Survey R.A.T. Survey Acidize with coiled tubing Coiled Tubing Specifications Working Depth (1.255 S.F.) Max. Working Pressure . Tensile Strength Tubing O.D. Tubing I.D. Wall Thickness Capacity Tubing Weight 16,500' 5,000 psi 15,300 lbs 1.00 in. 0.850 in. 0.075 in. 0.702 bbls/!O00 ft. 29.48 gal/ICaO0 ft. 0.63 lbs/ft. Cost Estimate C34-23 Coiled Tubing Acidization · 2. 3. 4. e 6. 7. 8. lO. l~+O0 gal 10% HC1 2100 gal 10% -12% HCl-HF Acid Additives Pump 1.5 days @ $1,300/day Tanks 1.5 days Lines 1.5 days Personnel 1.5 days Coiled Tubing @ $5000/day Miscellaneous Total' Add 10% Contingencies Say 1,400 4,600 1,500 3,O00 1,200 2,500 5,5O0 7,500 2,000 $29,200 $32,000 Acid Additives Composition 10% HC1 (Hydroch 1 ori c Ac i d) 0.3% W-35 (antisl udge) 0.4% F-75N (surfactant) 14 lbs/lO00 gal L-41 1.2% A-200 (inhibitor) 12% - 10% HC1-HF (Mud Acid) 0.4% W-35 0.4% F-75N 14 lbs/lO00 gal L-41 1.2% A-200 K~, MAt,~DPdBIS (~ AS OF AUOUS~: 3~ 1972 zNo: z°j/h' o-n.83o," 7" N-80' BUT'iYLESS 26// 0-8070' NOTE: 18~ P~ ~ 8680' T UBIt'!G: , S"EA22-J~OCK (220 ',IT) 0-7183' ltl 3=. 9.3,~ 'x-8o 7t83-8993' PE~. :8~108-8~'!150' ON-GO · 8~h13-a~h66' OR-OS ! 8~702_8~709~ '. ;. 8~720-8,7~8' 8'~ 766-8,7 7 ~ ' HC-~' 8~928-8~942~ . 2. 8, ?55-8,967 ' ~m-H~ P~ ].25-9~ 185' 9~198-9~ 278~ ~-~ 9~312-9~333' 2_> _] BALL VALVE o . XO $IY~WE ~ 8,035'. '. X-~F]]°PI.~ ~ 8,069' ' RH-I' PACER ~ 8,076' ~G //1'~ 8,233' Pulled :Jummy 8-28-~1 Pocket. open'to GN-G0 XO SLF~ ~ 8¢268~ cIosed . RH-1 PACER ~ 8~272~ XO SL~ f~ 8,79~' Open ~-9-YY RH-1 .PAC~ ~ 8~ 79R' " · K~ ~3 ~.8~857' .O~mmy RH-1 PACER ~ 8~896' RE-1 PACKER @ 8,970' X-NI?PLE @. 8 ~ 981 ' ' ' Q-NIPPLE @ 8:992 ' Kt~J //h ~ 8,932' Dummy XO SLEEVE ~ 8,967' Closed OCT] ~/aska Oil a Gas'toni TD. ~5301 ' I WESYERN E&P OPERATIONS OCT ~. ;;, ,!983 S H ELL..,,.ATLA NTIC--STA ND A RD ~ ........ TSN . ~L ~S~ : / ~ . I /:~ ~ / i -~ ~ ~-~ ~/ :t: · / ~, e:~& / :,; -~~~< -" I ' ,,, . / o~-~ ~"-",~' "~'"" " /~ ""-"/ ~'~' INJECTION WELL , / .,,_~, I ~ PRODUCING WELL PLUGGED & A~ND. , ~, ,~,-, ; , ~.~ . . ' ',/ '.' ~ 'i /! 'I I , ,'--~-~ "/ , ~ 0 4,000 ~~ ~i ~t~' / ', ~ SCALE IN FT~ ; l_ ~- I! ii /-u-/ ~ r~,. .... ' . STATE OF ALASKA ' ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WELL I~X Tnjector OTHER [] 2. Name of Operator Shell 0i11 Company 3. Address John Douglas, P.O.._ Box 4500, Kenai, AK 99611 4. Location of Well Conductor 32, Leg 4 @ 36.53': S and 53,31'; E from the Center of Leg I wh.tch ils at 541.65" N and 1596.41" W from the SE Corner of Sec. 23, T8N, R12N'. S.M. 5. Elevation in feet (indicate KB, DF, etc.) _ 105~' D.F 12. I 6 . Lease Designation and Serial No. ADI 1R7.5~ 7. Permit No. 68-107 8. APl Number 50- 733-20145-01 9. Unit or Lease Name HGS 10. Well Number C 24-23 11. Field and Pool Middle Ground Shoal "G" Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other ~( Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). See Attached. REEEIVED OCT 1 2 1983 Alaska 0il & Gas Cons. Commission Anchorage 14. I hereby certify that tl}e foregoing is true and correct to the best of my knowledge. Signed /1~~ Title Mgr. Prod. Admn. The space below for Commission use Date 10/4/83 Conditions of Approval, if any: Approved by' ORIS'NAL SIGNED BY LONHIE C. SMITE Approved Copy ..~_~/0~//turned .... By Order of COMMISSIONER the Commission Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate AU/~HORITY FOR EXPENDITUI~ PRODUCTION PACl FIE DIVISION HOUSTON LOCATION OF PROJECT A/qqqCX~RIATION NO. C£4-23 M~dd]e G~ound. Sh6a] F~e]d 9/]4/83J Cook Inlet, Alaska ~. I I I ~RK SHELL'S 33 % SHARE ORDER, ~PE DESCRt~ION NUMBER 1~ C~ BU~ N~-BU~ E~ i i R&R Obtain profile injection .$15,000 $5,000 $5,000 survey in C24-23 Non Operators Approval Not Required Requested by- J.H. Douglas T.S. Burns . · SU,--~O~A~ $15,000 $5,000 $5,000 i BUDG~ AVAIbABL[ IN BUOGET RETIREMENT EXPENSE , POSITION NEW CAPITAL FUNOS REQUIRE0 BY 8UOGET REVISION ~TOTAL COST ~ , b 5tO00 ' I JUSTI FICATI ON: See ~ched Justification Anchorago CONTINUED OVER. ~... ..... RECOM MENDED APPROVAkS i Justification Injection Survey C24-23 Middle Ground Shoal Field Funds totalling $15,000 ($5,000 Shell's 1/3 share) are requested to obtain an injection survey in well C24-23, Platform C, Middle Ground Shoal Field, Cook Inlet, Alaska. Well C24-23 was drilled and completed in December 1968. In 1969, Well C24-23 was converted to injection with an initial injection rate of 2900 BDW. In April 1982, C24-23 was acidized with coiled tubing. The injection rate increased from 1400 BDW to 2000 BDW. The rate has since declined to the current rate of 1500 BDW. The formation of bacteria and scale during recent frequent shut-ins is believed to be the cause for the injection decline. C24-23 is located on the southern boundary of Pattern #5. Pattern #5 currently produces 1700 BDO, 2700 gross, and is supported by 3200 BDW injection. Pattern #5 has previously responded well to increased water injection. Acidizing three injectors (C41-23, C24-23, and C34-23) is currently being evaluated to further increase water injection. Additional water breakthrough recently occurred in C43-23 (immediately north of C24-23) in one of its producing members. The breakthrough was noted by a 200 BDO drop in oil production with cut increasing to over 90%. The well is currently cleaning up and most of the lost production has been restored. With water breakthrough occurring in C43-23, it is recommended that profile information be obtained before further stimulation is attempted. This will prevent further stimulation of a watered out or thief zone. The profiles will also be helpful in determining which zone watered out in C43-23 and estimating the well's future productive potential. The last profile information for C24-23 was obtained in February 1979, and was scheduled for an R.A.T. survey in 1983 as part of the reservoir maintenance program. Your approval is recommended. ~]a~i~.gt Oi-~ & Gas Co~ Comm~ior~ Anchorage Prognos i s Injection Profile Survey C24-23 Status: Injection 1500 BDW at 3500 psi. See attached completion details for perforations, sliding sleeves, packers, gas lift mandrel depths, etc. Objective: Determine injection profile. Procedure: le Rig up wireline and lubricator. TeSt lubricator to 3500 psi. Make drift run to bottom. Record on log heading. Rig down wireline. 0 Maintain constant injection rate at 3500 psi pressure for 3 days prior to and during the survey. Record on log heading. e Rig up service company's lubricator (high pressure - wireline), stuffing box, collar locator, continuous flow meter, and radioactive tracer with ejector and two radioactive detectors. 0 Tie into depths with collar locator in casing. Log perforated interval (8108'-9440') with CFM and determine profile for watelr leaving tubing or casing. Be Use R.A.T. to determine profile behind tubing and vertical fluid movement behind casing. e Log tubing to surface with CFM to determine tubing leaks and/or fluid leaving tubing and re-entering at a lower location. If casing leaks are suspected, confirm and locate using R.A.T. 7. Rig down service company, continue injection. OCtl ~:': i~.i-~?. Alaska 0il & Gas Con'~_ t;omm~ssior, Anchorage:. c,o.24-23 · ' 'ns. oF ~uous~: ~, z972 · · ¢~STNO: 103/1¥ O-1830 7" N-80' BU'£TP_E.SS 2o~ 0-8070' NOTE: 18' 2UP ~ 8680' T~Zt'JO: ~ 1!~6~ N-80 0-7183' ~'-" 9,3~ '~-.8o ' 7183-8293' . . 8,).~13-8 ~466~ OR-OS ' 8,702-8~709' " ~7~0-8~798' 8} 786-8,77 f ~ HC-~' 8 ~ 8~4-~ ~ 885 ~ 8:P~8-8~p~ 8~ PS~-p~llO~ BALL VALYE ~ 289' X0 $ ,LEEVE ~ 8,03~'. X-NIPPLE @ 8,069~ RH-t PACkeR @ 8,076' ~G //1'~ 8,233' Pu]]ed ~ummy'8-28-81 xo a, 6ag°g g 'e pan't° GN-GO AH-1 PAC~R ~ 8~272'~' ' ~G /72 ~ 8~75R' Dummy X0 SL~ ~ 8~795' Open f-9-77 RH-1 PAC~ ~ 8j799' " ~ //3 ~. 8,8J? ' . Dummy XO S~]~ ~ 8,8~2,0pen'S-9-77 RH-1 .PACER 8 8,896' .' 932 ' Dummy XO SLEE~/E ~ 8,967' Closed X-NIPPLE O. 8,981. ' " ( .Alaska Oii& ~as'Oorm: ~ommi$~ior~ ~ ' An¢'~era~e PBTD. 9~475' ~ TD. 9,530' - ~z,- , WESTERN E&P OPERA"i'iO,,,S SHCLL,-ATL4 NTIC-STANDARD ' ~ I i i-t111 / 't4 A-O ~ I I ......... - tr .... ~--7- ---.-' __ ',. ~2-~ / ~t~ , ~ ~! t.~~--~ ' ~ / ~,'~:.~..~ 7 -I- , ~x-~ ' ' o - o,,-~, / { ~ INJ:C'- '-~ION W[:LL , :' ,/ ~ ~ ,/ ¢ PRODUCING W~L_ I~F~+~' ]- . ~P.m PLUGGED & A.~ND ~_~~ ....................... , ............ ,,. ,,t -- ~ ' ~ ,~,,_. o /~ t ' /,, ...... !_ · ,?..~-/; j~ 4ooo. ....... . ' I SCALE IN FT ' :-' * . STATE OF ALASKA ~' ,~,LASK~IL AND GAS CONSERVATION ~'-'h'MMISSION SUNDRY NOTICES AND REPORTS ON.WELLS DRILLING WELL I-! COMPLETED WELL OTHER F1 She!! Oi! Company 2. Name of Operator P.O. Box 92047 Worldway Center, Los Angeles, CA 3. Address 90009 Conductor 132, Leg 4 at 36.53' South and 53.31' East from the center of Leg 1 which is at 541.65' North and 1596.4'1' West from the South- east corner of Section 23, 'T8N, R12W, S.M. 4. Location of Well .. 5. Elevation in feet (indicate KB, DF, etc.) 105' D.F. NOTICE OF INTENTION TO: (Submit in.Triplicate) Alter Casing 12. 6. Lease Designation and Serial No. ADL I8756 Perforate I~ Perforations Stimulate ~ Abandon f-I Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other r"l Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 7. Permit No. 68-107 8. APl Number so- 133-20145-01 9. Unit or Lease Name NGS 10. Well Number C 24-23. 11. Field and Pool Middle Ground Sh0al "G" Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data SUBSEQUENT REPORT OF: (Submit in Duplicate) Abandonment Other O 0 0 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). · Please see attached. ECEIVED MAy 1 o ' 982 0il & Gas Cons. Commission ~,nc.~orag9 14. I_hereby certify that the foreg/~i'ng is true a~nd~orrect to.the best of my knowledge. Sign~~~C~//l~/7/~/-V' ~~-,-'V~JT) . Tit,e Mgm' Pr°duct~°n Admin~strat~°nDat. The s~ce below for CommiS~on USe For: B, Nevi 11 4-22-82 Conditions of Approval, if any: By Order of Approved by COMMISSIONER the Commission Date__ Form 10-403 Rev. 7-1-80 Submit "Intentions" ~n Triplicate and "Subsequent Reports" in Duplicate WELL SHELL OIL COMPANY RECOMPLETI'ON REPORT C 24-23 SHELL OIL COMPANY -- ii Middle Ground Shoal i ii ii ii ii iii i I 3/29/82 ! i L j ~1~.-I Unchanged i ~ i lmm i i ii ] i -- _ i iii· i IL ~11 _ _ _ · ii i i _ · i I ~_ i · I 11 I Il I I I i Il m ?oe-Ll ~eur. h ,d, 9.5,,30 ........ Wlarker Horizons 9,475 · -- IIII I II I II I I 'Ill I I I I Il II Jill Production Data C,o~rT,..oA. p. t _ · i C, ddOI.~.~--C&Z2,:,M/M. C.. lt. · 10-3/4 :.~! _. _ .f,.~mi .mi 1830' _ ~_ 7-ad,I. 26# .. u=,,~d -, 8070 · . 7'--~-[ 29'~ ,,=,~ .....8070-9530 -. ~' "~,X ~=~ ~~ ~ - ~ ii ii i i i iiii i m i ill JlJ Ill Il I-- - Ill· _ _~ m i i i Initial Production · ii 'GN~Go .8108/8140 .HK/~N 8985/9ij0 -GR/GS 8413/8466 ~125/9185 ' 8702/8709 "HN/H~ 9198/9278 · 8720/8~09 931~/9333 ' II I. ii HC/HD 8~66/8775 ...~R/HZ 9355/94~0 - HE/HF 882~78865 ..... 892~/8942 ' - ' - Ni/HK 89~5/8967 i i _ m · _ i ii n Im i i il u i i i mi I Adotl. Pr . D.--ta Calculated Potential -- i · i i _ il ii i -- il in i __ Bill i J II -- III mil ! I -- · -- -' imm m _ · ii i! iim I I · I __ _ ~ I I mm , ii __ i · ! i il mil -- 11 · ii __ [i i i ii I ill lB _ -- : i i __ I i __ mm · I -- I I I IJml mi J ~ i iiiii i -- i . mi ,1_ m m I Improve injection profile by acidizing the lowest zones (hk/HN~~)VE~ through coiled tubing· MAY 1 0 1982 Alaska Oil &.,Gas..~.,.o,,~C°ns' Commission MIDDLE GROUND SHOAL Kenai, Alaska 3/29/82 3/29/82 Platform C I ~ ! mlll iii m I II I III IIII I ~1 I II I · II I I · I I I ! I IIII STATUS' Currently injecting 1535 BPD into HC/HD, HI/HK, HK/HN, HN/HR, and HR/HZ. Last RAT survey results are as follows' C-24-23 Zone Percentage HE/HF 0.073 HI/HK 0.091 HK/HN1 O. 145 HN/HR1 O. 455 HR/HZ1 0.236 3-29-82 · PROPOSAL' Improve injection profile by acidizing the lowest zones (HK/HN, HR/HZ)through coiled tubing. / 12-00 PM Moved in, rigged/'up Otis coil tubing unit. Pressure tested to 5,000 psi. Hfid leak in riser. 2-1/2 hours repairing leak. 2'30 AM Pressure test to 5,000 psig. Good pressure test. to 6'00 AM Started in well with tubing. Tubing a't T.D. Made two runs through perforations while circulating injection water to clean out. Ready to pump acid. 8:00 AM Started Dowell pumping acid as per prognosis. 12'00 N Had all acid pumped and coil tubing flushed with 10 bbls of treated Cook inlet water, pumping 1/2 bbl/ minute at 3500 psi. Shut down Dowel l pump to repair leak. 12-10 PM Started Dowel l pump back. Pressuring up to 5000 psi and bleeding off to 2000 psi. Not moving much fluid. I ~ II I I I · ii '~ . ill i il I · i II i · ECEiVED' · MAY'i 0 1 82 .,--. Alaska Oil & Gas Cons. Con II I MIDDLE GROUND SHOAL C-24-23 -- iii i ii _ i i i - .. ~en_,ai ,,- ALASKA 3/29/82 RZPOI~I' 3/29/82 Pl~~~ - ~,~r~, ' '" ' - ~ ........ ' '~' ' ' fl. mm~w~ ' _ I III ! I ! I IL I IIII II II III I I I I I I ......... II Ill "' 1'00 PM Started out of hole with coil tubing. 1-30 PM Coil tubing started leaking in a weld between the well and the reel. Opened well to flow overboard. 2:00 PM Coil tubing broke at weld. Threaded end of coil tubing and screwed on plug. Tied ends of tubing together and pulled out of well. 4:10 PM Tubing out of hole rigging down. 6'00 PM Put well back on injection. ? ~qlas)(a Oil & Gas COr~S. Comrn/ssior~ -- I J Il I I I mi I m ii I II ii I m I I I I I mil I /'--x STATE OF ALASKA ALAS .~ OIL AND GAS CONSERVATIOI ;OMMISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator Shell Oil Company/'i, 3. Address p.O.-Box 92047, Worldway Center, Los Angeles, CA 90009 4. Locl4~n of Well Conductor 32, Leg 4 at 36.53' South & 53.31' East from the center of Leg 1 which is at 541.65' North and 1596.41' West from the Southeast corner of Section 23, T8N, R12W, S.M. 5. Elevation in feet (indicate KB, DF, etc.) !05' D._F. 6. Lease Designation and Serial No. ADL 18756 (Submit in Triplicate) Perforate [] Alter Casing [-I Perforations · Stimulate ]~} Abandon [] Stimulation Repair Well [] Change Plans D Repairs Made Pull Tubing [:] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 7. Permit No. 68-]07 8. APl Number ~ "~ 50-133-20145~01 / 9. Unit ~*l~ease Nam~'--~/ MGS ' ' 10. Well Number C 24-23 11. Field and Pool Middle Ground Shoal "G" Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other [] D 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed wOrk, for Abandonment see 20 AAC 25.105-170). Please see attached The ,pace bC~ow for Commis/n use F~r: B. Nevill 2-2~-82 ._. Conditions of Approval, if any: t Approved Copy Returned BY Order of Approvedby BY lO~t?41E C.SMITII COMMISSIONER ,heComm,$s,on Date Form 10403 Rev. 7-1-80 Submit "intentions" in Triplicate and "Subsequent Reports" in Duplicate AUTHORITY FOR EXPENDITUR/~ PRODUCTION ,J PACIFIC DIVISION J HOUS'iuN , LoC~r,~,' o'= ~c:~cr ~",^~o~ C24-23 PLATFORM C . ~.*T~ ..[.,,"~. j MIDDLE GROUND SHOAL FIELD 12/28/81 COOK- INLET. ALAS~ ~. ] ,,~~] ~u" ~OCATION NUMBER I II I II I lB II I IL ~RK SHELL~ RR 1/.,~ % SHARE , ORDER ~PE DE~RIPTION 1~ C~ ~~ N~-BU~ J~ NUMBER ,¢ ................ ~ .... R&R Acidize C24-23 injector thr.ough coJled tubing $40,000 $13,300 $13,300 Non-Operator approval not required Requested by: Q.H. Doug1 as B.N. Osborne R.V. Hill K. ~. Evans .,. ...... ,0,000 . 3,300' BU~ AVAILABLE IH BUDGET RETIREM[NT EXPENSE 'O$'TION NEW CAPITAl. FUNDS REQUIRED BY BUDGET .EVISION iTOTAL COSt ~ .$.] 3,30b I ~ '~ "T ~ ,~ I I JUSTIFICATION ..... SEE ATTACHED JUSTIFICATION MAR 1 ~ 't(L~a 0il & Gas COns. C°mmissiuu - CONTINUEO , ,,, , , OVEN; r * ' ' 'RECOMMENDtD APPROVA~ ii i i i i i i iiii i i i Ul ., iii L II I ~1 I II I ~ I ~-'~ JUSTIFICATION C24-23 Funds totalling $40,000 (Shell's 1/3 share $13,300) are requested to stimulate the lower Hemlock sands in C24-23, Platform C, Middle Ground Shoal Field, Alaska. The economics for the job are as follows' ' SHELL NET ~TOTAL GROSS Expenditure $13,300 $40,000 Oil Increase (BPD) 22 66 PVPAT @ 14% $120,000 $360,000 % PVPAT 900% 900% Payout (months) 3 3 (0.60)($120,000)- (0.40)(0.5)($13,300): $69,000 As noted by the last RAT survey (2/79), 46% of the injected volume in C24-23 is going into the HN/HR upper zone. The purpose of this stimulation is to improve our injection capabilities into the lower zones (HK/HN - HR/HZ) excluding the HN/HR upper. Increasing injection into the 3 lowest zones of the Hemlock will make our secondary recovery program more effective because these zones are relatively unswept in comparison with those uphole. As shown in the table below, the yearly production decline in Patterns 6 & 7 is much greater than the total average field decline (for calendar year ending Octo- ber 31, 1981). These rapid declines in the south l~ortion of the field are due largely to poor waterflood management in recent years. The HK/HN through HR/HZ zones contain 57% of the STOOIP in Patterns 6 & 7. In order to improve our recovery, we recommend stimulating these zones (excluding HN/HR upper) to increase injection volumes into them. We estimate that the recommended stimulation of C24-23 will increase injection into the lower zones by 260 BPD. Based on a 0.25 BO/BW injected ratio, we expect a production increase of 66 BOPD. YEARLY PATTERNS 6 & 7 10/80 10/81 DECLINE SAS MGS TOTAL FIELD DECLINE Gross Production (BBLS) Oil Production (BBLS) 39589 30382 23% 11% 19807 14302 28% 18% With the use of coiled tubing, we will be able to spot acid at the desired perforations so that selective treating will be possible (below the bottom packer). By taking this approach, we can avoid a much more costly(and most probably .unjustified) job of pulling the well, stimulating, and altering the downhole completion. This job would be quite risky because of the number of packers in the well (3) and the length of time the completion has been in the hole (9 years). In addition, because of poor tubing integrity (leaky gas lift valves and sliding sleeves), batch treating from the surface with diver_ters is un- acceptable. We feel that the reconinended treatment in C24-23 will make our injection program more effective, thus increasing production and slowing decline rates in Patterns 6 & 7.~ Your approval is requested. ~EC~V~D MAR 1 5 1982 A~asKa Oil & Gas Cons. Comm.~ssioi~ STATUS: OBJECTIVE: PROCEDURE: NOTE: 1. e o e e 6~ e 8~ ge C-24-23 Currently injecting 1535 BPD into HC/HD, HI/HK, HK/HN, HN/HR, and HR/HZ. Last RAT survey results are as follows: HE/Hr ~.073 HI/HK MAR i 5 1982 0.091 HK/HN1 O. 145 HN/HR.~ A!a~ka Oil & Gas Cons. Commission O. 455 HR/HZ~ fmchor~.~ O. 236 1. 000 Improve injection profile by acidizing the lowest zones (HK/HN, HR/HZ) through coiled _tubing. (Shut-off injection +48 hrs. before rigging up coiled tubing unit). Rig up slick line, test lubricator to 3500 psi. Run 2-1/4" tubing drift to bottom + 9475'. Tag and record depth. M.I.R.U. Otis coiled tubing unit and Dowell acidizing equipment. Test tree and coiled tubing to 5000 psi. Test hydraulic system and BOP. Run tubing in the hole slowly (no more than 100 fpm). Tag bottom (9475' PBTD), if fill is above bottom perforations at 9440', notify K. J. Evans (713) 870-2342 or (713) 531-8676 (home). With coiled tubing at 9440' spot 397 gal. of 7% HC1 with 0.3% W-35, 0.2% F-75N and 1.0% A-200. Slowly move coiled tubing uphole while spot- ting acid in order to cover all of the perforations (9198'-9440') with acid. Pump 8 bbls. of injection water to clear coiled tubing. Stop coiled tubing at 9185'. Wait 30 minutes after clearing tubing of acid and pump 17 bbls injection water. Run coiled tubing to 9440' spot 397 gal. of 12%-10% HC1-HF acid with 1.2% A-200. Slowly move coiled tubing uphole while spotting acid in order to cover all of the perforations (9198'-9440') with acid. Pump 8 bbls. of injection water to clear coiled tubing. Stop coiled tubing at 9185', wait 30 minutes after clearing tubing of acid and pump 15 bbls. injection water. (Repeat Steps 6 & 7 two times). After repeating Steps. 6 & 7 the second time, move coil tubing uphole to 9110'. With coiled tubing at 9110' spot 195 gal. of 7% HC1 with 0.3% W-35, 0.2% F-75N and 1.0% A-200. Slowly move coiled tubing uphole while spot- ting acid in order to cover all of the perforations (8985'-9110') with acid. Pump 8 bbls. of injection water to clear coiled tubing. 10. Stop coiled tubing at 8995'. Wait 30 minutes after clearing tubing of acid and pump 8 bbls inj'ection water. ll. Run coiled tubing to 9110' spot 195 gal. of 12%-10% HC1-HF acid with 1.2% A-200. Slowly move coiled tubing uphole while spotting acid in order to cover all of the perforations (8985'-9110') with acid. Pump 8 bbls. of injection water to clear coiled tubing. 12. Stop coiled tubing at 8995', wait 30 minutes after clearing tubing of acid and pump 15 bbls. injection water. (Repeat Steps ll & 12 two times). 13. After repeating Steps ll & 12 the second time, pump 200 bbls. injection water. While moving coiled tubing up and down through treated interval. 14. POOH and rig down. Put well on strip chart, return well to injection at 3500 psi and test. Report rates to K. J. Evans and J. R. McGregor in Houston. NOTE: While working on water injectors, do not leave coiled tubing standing on well without fluid movement. Blow coiled tubing dry with rig air after rigging down. If rig air is not avail- able, cover coiled tubing reel and keep heated or circulate 50% methanol and 50% inlet water. APPROVED DATE RV H: c k k MAR 1-5 ~982 /:~!~cka'Oil & Gas Cons. Commiss~oa 0-24-23 AUOUST 3, 1972 1. 8, 2)3 ' DU;-~-!Y 2. 8~759' 3- 8;857' DU~-~.I'Y' PFJ~". :8,!08-8,!40' GN-GO 8,~13-8, ~66' GR-G$ 8,702-B' 709' 8,720-8,758' 8,766-§, 775' ~C-HD 8.824-8.865' HE-H7 8,P5%-8,967 ' H~-H~ 8,98%-9,110' 9,198r9, 278' ~,312-?,333' ~,355-9,44o' )m-Hz~ ..; B~LL VAL~F~ @ 289' XO S~ @ 8,035'- X-NIPPLE @ 8, O69' RH-1 PACKER @ 8,076' KBG #1 e 8,233' XO S~~ G 8,268' . ~-1 PACER ~ 8,272' '~ ~2 e 8~75~' .- . XO S~ e 8,7~5' ~-1 PAC~ ~ 8,79~' K~ ~3 e 8,857' XO ~~ e 8,8~2' RH-1 PAC~ e 8,8~6' · KB~ ~4 g) 8,932' xo sI~n~ e 8,967, X-NIPPLE O 8,981' - Q-NIPPLE O 8,992 ' · . . TD. 9,530' Page 89 -COIL TUBING SPECIFICATIONS .Eclui pment Length Wi dth Height Po~'~-r Pack 8' 4'7" 6' 4" B1 o~out Preventer 4' 2' 5' Injector Head 5'6" 4' lO' Reel lO' 6" 8' lO~ Operators Console. 9' 8' 6' Weight · 6800 lbs. 538 tbs. 5500 1 bs. 12,800 lbs. 3800 1 bs. Description Standard Pipe._ Working Depth (1.255F) 12,500 Working Pressure/Max PSI 5,000 Tensile Strength/lbs. 10,000 Tubing O.D./in. 1.O00 Tubing I.D./in. .874 Wall Thickness/in. .063 Capacity of Tube/gals. per lO0 ft. 3. 120 Capacity of Tube/bbls. per 1000 ft. .742 Displacement of Tube/gals. per 100 ft. .964 Displacement of Tube/bbls. per lO00 ft. .230 Tubing weight/lbs, per ft. .630 Heavy-Wall 12,500 5,000 12,000 1.000 .840 .081 2.8 o .650 1. 200 .290 .810 PiPe. I · H c~ ././lc 1,0 o 77 ~' 7o t../ ?/z._ 'Z '5 I 00~ · $ I 'COfL_ ..... ',qcz ~ f I1= o .: · .. o . ~5~7 WELL SHELL OIL COMPANY RECO'MPLETI'ON REPORT ,,,,,,.,,.,, ,,,,,,_ ,¢~/,~o ......... - -flecom~ietion aa,te~. ,, , , ~,...o.../~'-.::4.~J , . Marker Horizons Il [ I I IL ,, , III I i I "c, asin~- "c,~sing _ '"c~sing "liner - Depth Z/y~,~.~,;~ ,, _ ~. s. o.¢ , cemented ~t . cemented ~t landed/hun~ at cemented thru peris, at landed/huna at top at _Squeeze Production Data Manner of Producing Gross Fluid-B/D, ~ , Clean Oil-BID. , -- Cut-~ Gravity=°A. P. I. StUnity~pl~n NaCl(t oz r) , Gas-M. C. Fi,' Gu Oil Patio Gasoline-Gal~om/M. C.F. , .... SL~e Tubing Orifice Ca~lng Tubing L Initial Production _Si~ned Adotl. Prod. Data Date i Calculated Potential Date i i ii i i i _ _ Il J i u i i ii J REMARKS (SHOW IlZl AND ~PE TO~I~ RUN) Hoved rlg ore; veil. Removed t~ee, r. Lgsed up riser '~-d"~P s~'ack. Tested BOP hydraulic functions tO 150O ps~. Held 15 minutee ~ o~. Unlanded:tubtag v/llO,O0~ hook load. - Pocket ~~lready unseat ' . Pulled tubing.. ~tnsled d~n all lewalry. RtgBed ~~er~ U*l. n8 ~o hyperjeSt/~oO~ reper'~oraced-intervals 8702-8709, 8636-~66, and 8108-8140, ~ound top of fill. at 9t03~ 'Rigged dovn Sehl~berger, Ran clean out assembly consisting of 6u bit, 2 6 3/6" x 30' drill collars,. ,7" 'casing scraper, 6 3/6" x 2 1/8 'x '16't stroke Limper sub, X over 3 1/2" IF modified x '3 1/2 ~Ig and tubing to surface, ~11 baa b~n backfiring .a J.'*' stream ever since r~ov/ng trna. ~hile shut in overnight, casing pressure increased to 40 psi,. : ,. . . ' ' - Finished runni~8 clean, out' string, Reverse' circulated out trom~.9403,~_to 9675 using 5000 B/D injected racer. Pill vas fine sand ..n~ .u~,na. .: .. ,. . : - . ,- .... '. - ,, , , _~ ' _ co~=mo~ A~ ~ o~ ~=mOD ,, CON=mO~ ~ SrA~rmo WOS~ { CASINO SIZE { DE~H SET (ORO88 OUT ALL BUT APPROPRIATK ITEM8) HOLE , ,.,= I.~o. I ,,o ,, q" d ~.~~' ~...,o.,.,..., 9~/ ~.....,.,~ ..... ::,., , ~/~ -- ~TION OF PUMPING EQUIPMENT (UNLESS WELL WAS ..~/~/~$ ~/~/~ .o~. ~c.. ~.~ ,.~ occ~. ~, ,~SU~T o~ ,,O~UC,N~ o. DRIL~ PIP~ ~z~s ~/g~ , , s~u~ ~ow~ O.~R~Z~ONS. ....~ ~iGNKD GHEL,L OIL COMffAN~ ' - . ...... ,..o. .,. _ ... .o. ..., I I'1" . , ,..L ..... L . ;I ! ... ' : " Ite~ed' opeta~Lon~ ac 6:00 am. conL'inued running tubing and " . je~[r.y. . , Tubings. sCopped .at~. 8[~5~ R.T... +, ~ried ~o turn t~bin~ .and work ' .-through .t:i:~ht Spot :w'/~h'.no re~u:[:~s~, Tigh~ epot feels' lt~' pac~r~ or RBN Puli out. of hole at 1;30 ~ to' rev'i~e ~un. ntn8 mt~ing and check Je~lty. Pound lwe~ packer guide biade~ ~uehro~ed in and shear pine ehea~ed: Lay dO~n packers.. Rig up 8ehl~berger. Run Ouibet~n ~ype A vi~e .kine. Set packet. COuld .not 8et pa~t 8123'R,~. Yulle~ ~lre line packer aha m"i8 dovn 8ehL~be~get. Suspended operations for night at 9~00 p.m, . . . . 7" 2~'easing ID 6.18a, drift 6.059 6" fo-ii Sau~e bi,'passed spo~ before running 5.875"OD . . . . . ~ After injecting overnight d~n casing aS' 200 B/D with 300 psi surface pressure', bled d~ casing ~ith no sustained backfl~ fr~ well, Ran I l/~' piano ~ite bailer to 9~672'. Rigged up end ran Schlt~berget high resolution sonar bore hole televisor wlch sonar casing caliper. The televiever shorted out but the caliper indicated ell. lpttcal shaped casing 4 3/4 - 5~ by 7 - 7 1/2" over 'intervals (DIL) 8,123 t.o 8,126 1/2 ( 3 1/2 feet) and 8~127 1/2 to 8,130 1/2 (4 feet). . . . . · . Pulled and rigged;down Schl~be. rger C~nced injecting 89 casin8 at 150 B/D ~lth 300 psi surface, pressure. Sene tn crew for Lwo days . off'. ~4 ...... CONDITION AT ~ OF PERIOD CONDITION ~ STARTIN~ WORK H~LE { CASING SIZE I DE~H S~ CCaOS8 OUT ALL BUT APPROPRIA~ IYSit) ~' ' DE~ ~gT (RD. OR DE.) TOP FISH (~) OR ,JUNK (~) DEPTH PRESENT ~FFECTIVK , BAD CSO. (C) OR LINER (L) , , i , NOTE--IN ADDITION TO REPORTING ROUTINE RECONDITIONING OPER- ATIONS, US~ THIS FORM FOR REPORTING THE FIRST INSTA~ ~TION OF PUMPING EQUIPMENT (UNLESS WEL~ WAS ORIGIN- ,,, ALLY COMPLETED ON THE PUMP), BAD CASING, FISH LE~ IN DRIL~ PIP~ ' HAL;, ETC., THAT MAY OCCUR AS A RESULT OF PRODUCING OR :SlZ~ ~ , ,. , , .... ....... SHUT. DOWN OpERATIOnS. · SIGNED PD298 (Rev; .o-o;~l r.n~ea In u.o.~. SHELL, OIL COMPANY/' R£CONDITIONIN~ WILL, NO, - - ~ (iECTION OR ~) COUNTY FROM PI'RIOD 'TO (TOWN'$NIP OR RAI~¢HO~ _ .... , , __ . , .. , . i I~.o work, In. Je:ctln.~ 150 B/D at 275 psi. PlannLn~ increa6e ~o 1200 psi. C-r6~ return Lo ~o~k delayed until 10/5/70 to a~att d~llVe~yr ~r~ HOUKOq 'of a tubing 'safety Joint - shear type. . . , . ' '~/~ AC' 1200.pst injected. 968. barrel, on 10/4/70 ~nd 962 barrela m ' Stopped. t.n~ecrtng. Bled .casing. Ran robin8 .t'.rin8 ms foll,~8: . . . · Eud, o~ '3 1/2" ~a/[ 8156 Safety joht shear type ; 8063 q landing nipPle. 8031' ~ I Packer 7991 * ., Sliding a leave 7962 KBN.-~6-~/ 1/~" 118~ gas lift valve 689~. KB~ (13 w/ 3/16" 1105# gas ll~t valve 5885 , .- -' K'BN-(12 ~j 3/16" 110~ ins Iii valve , ~ ~1 w/-3/16" 1095~ ~aa lift valve 2~36 I~nded~-atriu~. Picked up 2 112 it. Ran.q plu~. Set p~cker v/ 1550' psi aureate pressure. Pdlled Q plot, Landed donut. Removed BOP s~ack and. rta~z. Installe~ tree., ~emL~ tree ~o 3000 psi. Held 15 minutes okay, Connected up' lines and 'rec~en~d inJcction-a~ 9 ~ 10/5]~0 at 2500 · B/D-rate vi~h 2000 psi surface injection pre. ssu~e, . ~_. ~ Injected 143t barrels in 18 hours aL 2000 psis. _ ........ ' CONDITION AT ~ OF PERIOD CONDITION~TARTING WORK HOLE ~ CASING SIZE I DEPTH S~ (CROCI OUT AbC BU~ APPROPRIATE ITENt) ' ~ ' · IZ~ J FROM TO DEPTH (ORIGINAL) ~P PLUO (P) OR BRIDGE (B) D~ ~ (RD. OR DL) TOP FISH (F) OR JUNK (J) - DEPTH PRK6ENT KFFEGTIVF BAD CSO. (C) OR LINER (k) - _ ~ I NOTE~IN ADDITION TO REPORTING ROUTINE RECONDITIONING OPER- ATIONS, US~ THIS FORM FOR REPORTING THE FIRST INSTA~ ~TION OF PUMPING EQUIPMENT (UNLESS WEL~ WAS ORIGIN- ALLY COMPLETED ON THE PUMP), BAD CASING, FISH DRILL PiPE HOLE, ETC., THAT MAY OCCUR AS A RESULT OF PRODUCING OR $IZE~ SHUT DOWN OPERATIONS. -- ,,r ' r ' ,'" ' ' ] ' ' SIGNED SHELL OIL COMPANY 430 7TH AVENUE ANCHORAGE. ALASKA 99501 January 15, 1969 Confidential Material STATE OF ALASKA Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska Attention Mr. Homer L. Burrell Gentlemen: Attached are two copies of the Well Completion Report for our SAS Middle Ground Shoal C-24-23. Included with the report are the following data: Composite Log (Sepia and Print) Directional Survey (2) Well History (2) Very truly yours, R.D. Allen Division Exploitation Engineer Attachments Form P-~-7 / SUBMIT IN DUPLh?~! :' STA;I'E OF ALASKA <See ot,~r st ructions on reverse side) OIL AND GAS CONSERVATION COMMITTEE . i i WELL cOMPLETION OR RECOMPLETION REPORT AND LOG* _ la. TYPE OF WELL: OIL ~X~ GAS [~] -DaY r~ Other ~VELL WELL b. TYPE OF COMPLETION: ~ACK n~$vg. ~ Other EN OVER · - WELL . NAME OF OPERATOI~ Shell 0il Company 3. ADDRESS OF OPERATOR ' 2' : _' .- 430 S~venth ~ve:nU-e,~_ An~ChOrage, Alaska 99501 ~. LOCATION OF WELL ~-:Re~ort,:_loqati6n clegr~p and in a~cordan~oe wit~ any State requirements)* At su~face Cond. 32,~: leg 4 '~t:':36,53'8 and 53.31'E from the center of leg 1 at :541~i65'~i-'& ~/i596.51'iW from the S.E. corner Sec. 23, at top prod. interval re'po~ted below T8N, R13W, S.M. 8108 (7972'TVD)~426.50'~-N and 2507.86'E from the SW ..corner Sec. At. totalaepth "' 23, T8N, R13W, S.M. 9555' (9407 TV-D) 581;.59'N & 24~8'E'from the SW corner of 5. AP1 NUMFA{ICAL CODE 50-133- 20145-01 6. I,lc.&SE DI~_IGN&TION A-ND SERI. A~ NO. !ADL 18756 ?, IF I1N"DIA.H, A.LL~'J,-r~ OR TRIBE None 8. UNIT,FA~RM OR LEASE NAME Middle Ground Shoal 9. WELL NO. : C-24-23 (Redrill C-11-26) 10.. FIleD: Aa'ND POOL; OR WI~T Middle Ground Shoal n. sm:., ~., R., ~., Cmn'roM OBJF.~IVE ) Sec. 23, T8N~ R13W, S'M. 12. PERMIT NO. 68-107 Sec. 23, T8N~ RI~3~ S.M, . 1~-24-68~ t2'12-68 ~' -~ 1~- 7-6. 105' D.~. MI,LW ._., a - TOil'AL...__ D~H,__ ~ ~TVD 9: P~U~: ~ MD & ~D . ~ ~'x'~ CO~., 21. INTERVAbS 9555' (9407'T~) 19475' (9328 ~ aow~, 3867'°~"~ ~oo~s. 9555' ' _ PRODUCING ~VAL(S), OF ~S C~M~TIO~P, BO~, N~E (~ AD 'rvo)* ~. W~ DIREC"I'ION~ - . SURV~ ~DE . "G" Pool 9~60~ (9293~T~) - I Yes :DIL, .BHC,.FDC~ HRD~, and:CB,L . . -- ~-~,5. - " CASI~TG REC~DI~D (Report all strings set in well) CA.qTNG STZIq] WEIGI-IT, HOLE SIZE 10 '3/4" ~ . 26. LINER RE C O.~D SIZE ' OP (MI)) BOTTOM (MD) [SACKS CEMENT* omb at ion i 28. PE~O~TIONS OP~ TO PRODU~O~ (Inte~al, size ~d humber) four - 1/2" jets per foot-: 8108-8140', 8413-8466'~ 8702-8709', 8720-8758', 8766-8775' , 8824-8865',-~vz~-~z'~ ~'~ , 8955-8967', 8985-9110', 9128-9185', 9198-9278' 9312-9333' 935,5r 9440' ~ODU~O~ DATE FI~T P~ODUC~OH '[ P~ODUCTIOH M~I'HO'D (Flowh~g, gas life, pump~size and type of 12-17- 68~ Gas DtT~ O~ T~l~, [EONS TES~ '[~OliE SIZE [~D'N FO~ OI~BBL. I 930,! I I ~1'. DmPos~o~ o~ ~s (~otd, ~,,d Ior ~*~, ~e~ted, etc.) fuel ~nd ven~ed · . , CFa%I]LNTING RECORD I AMIOUNT PULLED . 27.. ~UB~G (MD) ~ZE DEPYH SC (~) [ PACII~t SET (~) ACID, SHOT, F~'URE, C~NT SQU~aE, ~C. l~W,~,au OF OIL AND GAS 'ANCHOR:':3~ WELL STATUS (Produchag or shut-in) Producing G~S--1V~CF. WATEi%-~BBL. ! G~-O~ ~EO J 4o9 J ~ ' ! 495 WA'r~B~. J OIL GRlVrl' ~-~I (C~.) [ 96 ~ 33.1° _ TEST WITNESSED BY S2. LIST O~' ATTACHMENTS Well History (2). DIL 2" (Sepia & Print), Directional Survey (2) ' ~ ' ' ' e ' e oi a~d a"t: hed information '{s complete and correct as determined from allVavatlable records 33. I hereby eertff~~e~~~ j/////'f~l~f~ - DivisiOn Exploitation Engineer , JiM SIGNED F~ ~~~ TITLE ' ' DATE i (See Instructions and Spaces [or Additional Data on ~ ' :;'. ~;-~ ~".,, t. INSTRUCTIONS General: This form is design% for submitting a'complete and correct wel completion report and] log on all types of lands and leases in Alaska. · , Item: 16: Indicate which,, elevation is used as r~ference (where not otherwise Shown). . for depth measure- merits given in cther spaces on this form and in any attachments. , . Items '~0, ~,ncl 2-:2:: If this wel.l, is ¢'ompleted for separate production from more than one interval zone · (multiple completion), so stai.e in item 20, and. in item 22 show the p~cJucing interval, or intervals, top(~), ,bott0r'n(s) and name (s) (if any) f. or..only tl~.e interval reported in item 30. Submit' a separate report (page) on this form, ade, quately identif-ied,~ for each adctitional interval to be seperately produced, show- :. ing fha adlditioa~l data pertinent.to su.ch interval ......... , Itern26: "Sacks Cement';: Attached.' supplemental records for this well should s'how the detsils of any mul- tiple stage' cementing anti the location of the cementing tool. Item '~8: Sul~mit a separate completion report on this form for each.interwl to be separately produc"~l. (See i~structiOn for items 20 and 22. above). .. tMARY OF FORMATION TESTS INCLUDING INTERVAL T~TED, P~URE DATA ~ ~OV~ OF OI~', WA~ AND MUD NAME MEAS. D~ ~U~VERT. ', "E" Pool 8096 7 960 · ~ ~ "F" Pool 8435 "G" Pool 8700 8558 ~;~ DATA, A~ACtl B~IE? D~CglPI~O~S O~ LITIlOBOGg. POROSITY, F~&C~, ~PP~T DIP8 ~ND I)E'PEC~'EI) SHOWS OF O1~, G~ O~ W~. .~. . . .. ..~, 'Middle GroUnJ Shoal ,,, (FI. EL, D,) Kenai (COUNTY) AY' , D£PTM$ DRILLING REPORT ~OR PERIOD · ,,.November !7~ 1968 w,,.,. ,o C-..~24- 23 Section 23 T8N, R13W, SM - (TOWNSHm OR RZMARK$ 196 Surface Location: Conductor 32, leg 4 @ 36,53'S & 53.31'E from the center of leg 1 @ 541.65'N & 1596.41'W from the SE corner Section 23, T8N, R13W, S.M. 374 3687' Well C-11-26 was plugged back to 3687' 3687 7057' Spudded 430 hr 11-24-68 at a depth of 3687' Drilled 9 7/8" hole to 7057'. Mud 72-74 Pcf. Turbodrill #1, 3687-3722' faced N60E. 7057 9555' Drilled 9 7/8" hole to 9555'. Mud 73-75 pcf. Conditioned hole for logging. 9555' RAN DUAL INDUCTION LATEROLOG: RUN 1: 3000 TO 9551' COMPENSATED .FORMAT.!0N DENSITy, RUN.l,. 64Q0 ~9 9554', BOREHOLE_COMPENSATED ~ONIC ~LOG~_ RUN 1~ 6400 TO 9544'~ AND 4-ARMHIGHP, ESOLUTION DIPMETER~ RUN 1:5000 TO 9554'. 9555 ' CEMENTED 7' CASING AT 9530! WITH 960 SACKS. Ran 7", N-80, Buttress thread casing~ (26# 37-8070~ 29# 8070 to 9530') with guide shoe at 9530' and self fill differential collar at 9483' and 18' pup joint at 868( Cemented with. 200 cu. ft. fresh water ahead of 960 sacks class "G" (117 pcf' slurry) containing 1% CFR-2 and mixed with fresh water. Displaced cement with 2075 cu. ft. sea water. PBTD 9475 ' Bumped plug with 2000 psi. Flanged up and tested B.O.P.E. to 2000 psi. tLAI{ SPERRY SUN DIRECTIONAL SURVEY A~YD SCHLUliBERGER GAP~tARAY - COLLAR - ~E~MEN~ Bq~ LOG. RUN 1.:, 6600 TO 9466'. Ran tubing to 9458' and displaced salt water with diesel. Landed combination 3 1/2 and 4 1/2" tubing with shear sub at 8065' and Packer at 7999'. Tested tubing to 1000 psi. Set packer at 1500 psi and sheared sub at 3000 psi. PBTD 9475' 17 PBTD 9475 ' Gas lifted 239 Bbls diesel. Perforated with four - 1/2" jets per foot. 8108-8140', 8413-8466', 8702-8709', 8720-8758', 8766-8775': 882~.-8865'~ 8928-8942', 8955-8967', 8985-9110', 9128-9185', 9198-9278'~ 9312-9333', 9355-9440'. Ran Pressure Survey. Placed well on production. Released Rig 0300 hrs 12-17-68. REO:iVE JAN 1 ? 1969 DIVISION OF OIL AND GAS ANCHO~:vgE ",' ~ , , ,, dELI.. WELL NO. C-26-23 CONDUCTOR 34 ~'." 'D",' .... ~;"~V-- 0 "D'I;R .... -CO,JR ............ DTVD ..... a' ~ 0.75 S= aS. 88. 87.a9 ~ ,~ . ._ . - ';,' 4..., .., a .!, ....... a,,j. r5-'7 - SW 65.~ ....................... ~,.-3e 42.9~, /,9,". 2.09 NW '75. 33. -52 6.----'3-';. 25-'NW-83-, ....... 32 · .................... 3 ~. 94-' 5~8.~ z..25 -,,,"'"" 80. 32. 3i.91 ..... 59-2 ~.- ..... 5-. 2 5-',qW .... 8 '-3'~ ..... 3 ~. ................. .33 · 85 623. 6,,50 NW 79. 31. 30.80 .... ~ 5'7 .- ........ C,,J75 ,,.,'q"~ ..... 83-"' ......3 a.. .............. 590. 7,,25 SW 8!. 33. 32.73 '-"72i .---T';;"25--SW .... 7-3~"-7 ....... 31 · ................. 30.75 ....... 7i9.73 ............... 0 755, 7,75 SW 6~. 36. 33.68 753.a2 0 _. .... 'v,~( - 7,,OU ......SW,.-"aS. ....... 3I. ........... 30.76-" ~'/. 5,,75 SW 27. 3~. 30.~a '- ~81'. ......5',,'5"0-5W 36. ....... 6~-* ............. 63.70 ai', 63. 32.77 ~. 6.75 SW -'!07'9 · ...... 9-,7 5'-'S9 ..... 67-,-~6'5. .............. 16 2 · 61 !205. 12.25 SW 81. 126. 123.13 !'229. ........ 12'"00 .... SW'"75. 1260. 10.75 SW 71. 31. LEG a OBJ. 585W TVD h a17.99 660~98 ..... O.O0 493,95 O.dO "-525,91 .............. 0.00 557.82 O.CO 591.68 ............ 0 -.00 622.68 0.00 656.25 ................ 0.00 688,98 0.00 .00 784,19 .......... 0.00 815.0z, 0.00 878.74 ........... 0.00 911.51 u,O0 t07~.13 ........ 0.00 1197,26 0,00 !220.74 ........... 0.00 1251.19 -1292', .....1-U';OU-SW ..... 65-, .... 32', .............. 31.51 ..... 12~2.71 ................... 0.00 ' i~2a. 10.25 SW 65, 32, 31,48 131a,20 0.00 l.~SS. II.00 SW 59. 6~ 60.8& 1375,06 ........................... 0.00 I687. 8.50 SW 46. 101. 99.89 'I "'"'0 .............. "' ....... ~' ................................. op .,. ~.:0 .... SW .... 41. 63'. 62.30 1611. 9,75 SW 46. 61. 50.11 -i7-0'Z4'7-I"2'."0-0 .... SW ..... 5 2* ........... 93. ................... 90. 96 i770. 12.50 SW 55. 66. 66.43 1476., .95 0.00 1537,26 ................... 0.00 1597,37 0.00 i'688.36 ........ 0.00 1752.78 0.00 DECE -2'03B';; ....1"3","25 ...... SW ...... 61", i ..... 9'5. ................ 92.47 2013,45,~j~" 0!00 -2186, ..... I3-,'25 ..... SW ...... 6-4". ............. !"23". .......... 119.72 2256.73~ 0.00 1 ~2~13 ia.50 5'¢' 57 127. 123 49 2~7~.2~~ 0 ..... 2~-:)~,8. .... ..~.2,T'~ ....... ~ .......... SW-"5"8"' ........ I25'% .............. I'21.57 ..... 2~99.89~ ~ ~~. 19.50 SW 70. 126. 122.5! 2622.~!~-~ 0 .... 27q~I'~>"'OO'SW'-70. ......... 130' .............. i25',!~ ' 2748'55~ 0 267o.2 o 30'50.5'1 ~ 3200o04~ 0 -3-3"44,7'o' ..... o 3495.76 0 '3554.29 ......... 0 . O0 ! · 00 .......... 2 .00 -._ O--C~ , O0 .00 · 00 .00 .... 2920. 15"00 SW 71. 126. 121.70 3 ! ~, a'-. ....... 1'6"'J50 .... 5W'-75"", ............. I a 8 · ............. 180 25 .... 3265. 17.75 SW 78. 157, 149.52 -"Z4.2~-';' .... I-9-,' 00--SW ..... 80V'--15'3-' ................... I'Z+ z.~ . 56~ ~3578. 19.25 Sw ~5. 160. 151.05 -3"6V-;;-0-'-~---I c.',r,;2 5- -S'W "'7'8 , .......... 62. ' - 58 · 5 .3 MBER 36.58 36.62 36.33 55.6~ 35,31 3,'+. 65 34.16 34.81 35.95 37,96 "+8.36 5i,ll 62.03 66.21 67.5O 69.38 71.73 74.i~ 80.2~ 90,60 9706~ 105,06 1i6.96 125-16 134.32 145.38 155.93 6~.1~ 8i,5/, 9~.12 03.56 213,92 224,67 235.29 249.il 259.06 267~7i 272.31 276.56 19 68 E ~a. Sl 51'5o95 52,64 a~. 70 45,bi ~O.2U 26 22,15 18.56 15 0.99 O.O0 0.00 O.OO 0 .Ob 0.00 .. O. t)u 0.00 0.00 0.00 0, CO 0 oOU 0000 0.00 0 . 0,.~ 0.00 _ _ . ~ DOG LEG ........ SEC. OlS'~ C,.O0 0.00 -51.i2 0,00 5.20 ....... -50,~5 0,00 /' ,0(3 -49.47 0.00 .... *.66 ........ -~7.70 0 .Go ~ .18 -45 0 ,Uo b .03 -~2.30 O.Oo 4.Z~ u .00 1 .p4 ..........-~5 0.00 6.08 -30.93 O,oo ........... 3,25 .......... -27. U.O0 3.'7~ -22.~2 0,00 .............. ~.i9 ......... : ..... -19. 0,00 7,56 -18.25 :3.OU ..... 1.~3 ............. -14.25 O. u~ q.77 -it · Zo 9.91 ............. z*'6 i ................. 15'; zo 35.32 Z .U9 41.95 41.14 ~ .~ ~6.o7 ab.ol ~.'77 52,~o 51,64 ....... ~,Ii ............... 57.70 56,80 0.78 66.94 ........... 2.15 .................... 73,6~ 77,0d 3 .~8 bS.go ~3,7~ 1,17 ....... ~1.9~ 90,97 2.19 99,7'~ i06.20 ..... 2.9i ............... i15.99 i17,91 I .~ 12~.~7 !3~.79 ............ 1.68 ................... 144.98 i52,95 0.5~ 165.u2 17!~97 ........... 0.5~ .......... lo4.91 i 97.97 o.~k k i i. ~ 7 277. i7 ...... O. 27 ................ 2~3. ~ 8 30~.81 0,42 322 · Z9 ~3a,36 ........... 0,38 ............ 352.67 365.1~ 0,52 416 · 77 0','98 .........gDO, 90 463 . 59 0 · 97 4'~q · 40 ~i2,64 ........ 0','91 ................. 534,02 565.19 i00~ 5~b.'77 585 .'i9 ...... ~ ,TZ ......... ~07.06 S687. 1,8,75 SW 7a, 47. a4.50 373~, !S.O0 S',' 86, ~2. 4.9.q8 ....... 3030' ..... 1~5,25 .... SW' 87, ...... 91' .... 87.79 '~7, 13,50 SW 85. ~fi7. ~52.66 ' ~:~1'~ .... ~'2.2:-sw-ae, ":~. !~o,~ -- :a 55'"~-~'0-Y00'-'-N'[~ .... 90" ..... 160, .............. ! 57 · 56 a681. 9,00 NW BB. 126. t2~.~ .... 473~,---' 8.50-- NW '"87. ..... 157. ......... 155.27 ~889. ~.00 NW 89. 151. 1~9.53 .... ~-4~4~. ......... B.29~ ....q.~'," ...................... 86. 159. i57.35 5!7~. 6.75 NW 81, 126. i2~.53 .... 526-8~-9'.'25 ...... N-V~/ ..... 79, "94. ................. 92.77 5397. 8.75 x:w 77. 129. !27,49 ...... 55527 ~"~-O0-N-W 77' ...... 155. ............. i53.a9 ' 3598.80 3648,7B 3736.5B O.UO 3889,24 . ~039,73 419!o03 ~8,50 .............. 0,00 ~4~,05 3.00 4628,32 ...... 0,00 ~777.85 0.00 4935o2i 0.00 5059,74 O.O0 5152.52 ......... 5280.02 0.00 5433,51 0.00 594.0. ..... 60.6'6. ~','"7'57'-N W .... 74'. ......... 1'2 5 · .............. 125.12 6187, 6.75 N',,,' 69, 121. 120.18 ......................... : ..... i- it,,/ ..... 6384. 6.25 N: 6'5" ............. 197' .................... 195 82 .6a78. 6.00 NW 56. 94, 93.48 &.ll. 5o00 N~/ 66-°' ......... 33. 32,81 6.69!. 6.00 NW 62. 180, 179.01 7.=0., NW 77, 126. 124.92 5558.a3.. 0,00 7-,7'5 ..... Nw .... 72-', ..... 158.- ............. 156.55' "5714,99 ........ 0.00 7,50 NW 7a. 104. 103,11 5818,10 0,00 5943.23 u.O0 6063.39 O.OO 6259.22 0.00 6352.70 O.wO 6385,52 0.00 6564.53 0.00 ........ 6 ? 5"5-j "6'"'-"~. 5--'N'W ..... 6':0-', ....6'0 ' ............ 653'. S 1 .... 6628.15 ........................ 0 · 00 6961. 6.75 Nw 63. 206. 20~,57 6832.73 .... T06-~-"; ....7-;'2' 5'--NW ..... 5'~', i"01 ', ................ i 0'0 '. 19 ' 6932 · 92 .............. o · 00 7!78. 6.75 Nw 52. !16. 115,!9 7048.11 0.00 ....... ~30'~T- '6".25 ...... ~(--'52-' .... 126. .................. i25.25 ..... 7173,37 ................. (.) '7429. 6.00 NW 48. 125. 12a,3l ....... 7 55"5 ~ .... Si'00 .... /q g '-' ~- 6"'2 ...... 1'3 s · .................... 1 ~ 5,25 7-~-~7. 6.50 NW ~5. 172, !70,89 ........ 7~. . 7-~ .... 7'~-00"-:~{/'"' 4 5'~- ....... 140. ............. 138,95 ~02i. 7,50 NW 45. l~a, i~2.76 ~i'5'S-; ........ S";-'0'0-r%~ ..... S-~: , ..... i37-, ............... 135. es 83~2. ~.50 NW 36, 184, 181.97 ~ n'6"l'l-'~ '8-[7 fl--~] Rr-3'5-',--i'6"9',~ ............ i 67 .'03 8679, 7,25 NW 37, 168. !(~6,65 7297.68 O.O0 7432,9a ............. O.O0 7603.83 0,00 7742.79 ..................0.00 7885.55 O.O0 8021422 {~'~ G.O0 820:. 2 0......O... 0.00 8536.89 ~':l.~ O~C'O: 2~Z0.72 28i. 72 2~2.97 26~. 7," 285.74 285.05 283.83 2~3.47 281 278.88 275,9~ 271.58 266~73 2~3.0~ 256 · 252,70 248,62 2~3,52 234.46 229,06 220,23 21 ~6~40 i99,27 173.69 163,52 i50.05 12a.69 109,6 7 87,57 66,61 ~9,87 ,00 0.00 .- .... ~96 J ..... 7-vn 0 .... 5~-,^~---3"0-'. ..... ! 17 .' .................... i ! 6. i 2 8653.0 ? -2.~73, 7.,O.O--'NW 30. ............... 77. 76~42 8729.44~:~OO 29 68 7 2 2 9017. 5:00 N..f 27. 76 7~.5:.. 8872.62 . ........................ 9'6 .'6 9212. ~.00 .Ne,~' 27. 98. 97.~6 90~6.5! ~ 2.88 0 : 22. 53. ................ 52';68 .... 91't9.19'~ 8,23 .... 'i"9i"6'~ ...... 8%-2-5 ...... :~"' ..................................... ~ ............. 5 599 514 6.37 674 7u7 763 806 8.27 [:50 869 ~8~ · 71 ........ 2.97 ........ 62 ! · ~9 · 0~. ~,66 · 42 i .i~ o~w.dO · o~ i .GO 719. ~9 · ZO 0.84 ~05,14 ,47 0,38 849.03 · 16 u.7i 890.16 ,9~ ~.~ 904.0~ 92 97 98 lO0 102 102 103 3.11 0.46 4,13 0.48 0.16 0.40 959.50 0.42 O .45 979 3.47 0.:35 . 991.79 7.70 ............ 0".'6'0 ......... l'OO~ .61 u.98 0.49 lo18.40 0.42 ..... o,~ ...... i02~6.97 9.40 0.29 104.5.56 2.55 0o00 i048,58 9.16 0.23 !05b.~2 0.77 1077.i0 0.29 1090.~)9 1057.66 ...... 0.gal .... 1100,o9 109'5 .al 0.6U 1 i lO · 07 1i09.22 d.~O £120,~0 11!~,93 0,40 I129.~I 1129 1i42 it68 i1~0 1196 121,0 1223 12~0 125 i25 · 15 .............O'ib .......... llb9 · i4 ,92 O.~O I151~8b .99 0,~6 i162.62 · 2J 0.35 i174.70 .~0 U.3i !i99.U9 ./5 ...................... O'"il / ............... iz~/,~5 ,5i 0.91 1223,i8 .64 ......... 0.77 .... l'~Zg.gl 5.b3 O.OO 8.92 ......... i.iz .... 2.~2 O.~ 1239.16 I ,97 0,26 1246.95 4.13 ..... i,ii ...... 1248,64 mmSBo 6.50 ~'^I 20. !73- i7~.88 9555. 6,75 N'..^I 19. i17. ii6.18 929! .08 26.63 9407.27 39.64 0.00 0.00 SHELL OIL COMPANY 430 7th AVENUE ANCHORAGE. ALASKA 99501 January 3, 1969 CONFIDENTIAL MATERIAL STATE OF ALASKA 3001 Porcupine Drive Anchorage, Alaska 99501 Attention Homer L. Burrell Gent lemen: Enclosed is the Monthly Report of Operations (2 copj~/~or December, 1968 for our Middle Ground Shoal wells ~7 24- 23~nd C-41-23. WCH~br Enclosures Very truly yours, R. D. Allen Divi~sion Exploitation Engineer S'HELL, .O]L COMPANY 430 7th AVENUE ANCHORAGE. ALASKA 99,.501 DEC 3001 Porcupine Drive l,]ovember~ 19bB~ ~or ot~r Mid'dl~ ~o~n~ S~ai ~ell~ 0-II-20 and~ WCH/ces Eric bcc: Area Production U. S. G. S., Attn W. J, Linton Sr..-.,t~, of A~-k~ Division of ~ .... d,~ Attn l"orm No, p--4 REV. 9-30-67 STATE O,F ALASKA SUBMIT IN DEPLICATE O~L AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS API NLTA~ERICA3~ CODE 50-133- 20145- 01 LEASE DESIGNATION AND SERIAL NO. ADL 18756 1. 7. IF INDIA.N, ALOTTEE OR TRIBE NAAIE 0~L ~ o*s ~ OTaE~ None W~LL WELL 2. N~E OF OP~TOR 8. ~'IT,F.~M OR LEASE NkME S~LL 0IL C0~Y Middle Ground Shoal ~. An~RESS OF 430 Seventh Avenue, Anchorage, Alaska 99501 4~ LOCATION OF WELL Cond. 32, Leg 4 at 36.53'S and 53.31E from the center of Leg 1 at 541.65'N and 1596.41'W from the S.E. corner of Sec. 23, T8N, R13W, S.M. 9. ~,VELL NO. C-24-23 (redrill C-11-26) 10. FI~.T.r~ A_'~D POOL, OR WILDCAT Middle Ground Shoal 11. SEC., T., R., M., tBO1'I'OM HOLE OBJECTIVE) Sec. 23, T8N, R13W, S.M. 12, PERMIT NO. 68-107 13. REPORT TOTAL DE~TI-I AT F-~D OF MONTH, CPI. A. NGES IN HOLE SIZE, CASING ANT) C~---¥IENTING JOBS INCLUDING DEPTH SET AND VOLU1VIES USED, PERFORATIONS, TESTS AND RESULTS, FISHING JOBS, JIo-NK IN HOLE A.ND SIDE-TRACKED HOLE AND A~TY OTI-IER SIGNIFICANT CHA~G.F,S IN HOL~ CONDITIONS. Drilled 9-7/8" hole to 9555'. Ran logs. Cemented 7" at 9530' with 960 sacks. Ran logs. .~ Ran tubing. Perforated with four, 1/2" jets per foot, 8108-8140'', 8413-8466', 8702-8709', 8720-8758', 8766-8775', 8824-8865', 8928-8942', 8955-8967',. 8985-9110', 9128-9185', 9198-9278', 9312-9333', 9355-9440'. Placed well on production Released Rig 0300 hrs. 12-17-68 DIVISION OF OiL AND GAS At ~ C i ;:? ';:.,":S E SIG~ -.- .- ~TL~ Division Exploitation DATE ,, January ~ 1969 NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be fileO in duplicat~ with the Division of Mines & Minerals by the 15th of the succeeding month, unless otherwise directed. Form N~. P--4 REV, 9-30-67 STATE OF ALASKA SUB=rr IN DEPLICATE OiL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS APl NUAIERICA~L CODE LEASE DESiGNAiION AND SEIqlAL NO. ADL 18756 1. 7, IF INDIAN, ALOTYEE O2 TRIBE NAAIE WELL WELL OTHER None 2. NAME OF OPERATOR 8.U%'IT,F.~RAI OR LEASE NAAIE Shell 0il Company Middle Ground Shoal 3, ADDRESS OF OP~TOR 430 Seventh Avenue, Anchorage, Alaska 4. LOCATiON OF W~J~L 99501 Conductor 32, Leg 4 at 36.53'S and 53.31'E from the center of Leg 1 at 541.65'N and 1596.41'W from the SE Corner Sec. 23, T8N, R13W, S.M. 9. 1VELL NO. C-24-23 10. FIELD AND POOL, OR WILDCAT Middle Ground Shoal 11. SEC., T., R., M.. (BO~'TOM HOLE OBJECTIVE) Sec. 23, RSN, R13W, S.M. 12. PgRMIT NO. "]3. REPORT TOTAL DEPTH AT END OF MONTH, CI-L~NGES IN I-IdLE SI~E, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AArD VOLUIVIES USED, PERFORATIONS, TESTS A_ArD RESULTS, FISHING JOB,S, JLrNK IN HOLE AND SIDE-~CKED HOLE AND ANY OTHER SIGNIFICANT CI4_AN~F~ IN HOL~ COiXFDITIONS. Spudded at 3687' (C-11-26 plugged back) on 11-24-68 Drilled 9 7/8" hole to 7332'. RECERVEI) ANCHORAGE 14. I hereby ce rtify ~~~~//~'~~Zct S~ON~D .//~/~~-~,,m,.r. Division Exploitation En~qFer ~C 9 ~§6~ NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be fi/ed in duplicate with the Division of Mines & Minerals by the 15th of the succeeding month, unless otherwise directed. SHELL OIL COMPANY 430 7TH AVENUE ANCHORAGE. ALASKA 99.501 November 19, 1968 Private and. Confidential STATE OF ALASKA 3001 Porcupine Drive Anchorage, Alaska' Attention T.R. Marshall, Jr. Gent lemen: Enclosed for your approval is our Application for Permit to Drill well S.AoS, M°G.So C-24-23 from our Platform "C't. Also enclosed is our check in the amount of $50.00 for the filing fee. Enclosures: Filing Fee Check (1) Application to Drill (3) Location Plat (3) Division Exploitation Engineer Blowout Prevention Program (3) 1968 Re: ~iddle Crotmd Shoal C-2&-23(~edrtll C-11-26) Shell Oil Co=paity, operator ~ Oil Coapa~y &30 Seventh &~e. ~.losed please f~ the approved ~plicatio~ for pet~tt ~ drill t~ ~fer~~ ~11. ~e~ s~les ~ ~re chips are ~t r~~. V,~ t~ly yours, Thomas I. Y~;sh~11. 3r. Petroleu~ Supe~sor ~los-Jre FORM SA - I B 125.5M 8/67 MEMORANDUM TO: I'-' FROM: State of Alaska DZVXSKII 0Y OIL AND ~tS DATE : SUBJECT~ IievilllIr 27, 1~ FORM SA - I B 125.5M 8/67 MEMO RAN DUM TO: I-- FROM: State of Alaska DXVXSXOM OF OIL AND 6aS DATE : BavmllIir 27, 1968 SUBJECT, ~ (JTOJlJd ,~bOSJ, ~-2&.,,23 (bd~'tXX C.-XX-~) ~-- A. P I. 50--l.3.33220145-01 ..... · SUBMIT IN TRIP. (Other instructions Form P--1 reverse side) i~-~V. 9~30-67 STATE OF ALASKA OIL AND GAS CONSERVATION ,COMMITTEE APPLICATION FOR PERMIT TO DRILL, DEEPEN, OR PLUG BACK l~t. TYPE OF WORK DRILL J~ DEEPEN I-J PLUG BACK J--J o,L [] w~.~.L°'s 7-1 o,H~R ~ONE ~O~ WELL 2. NAME OF OPERATOR Shell Oil Company 3. ADDRESS O~ OPEIIATOR 430 Seventh Avenue, Anchorage, Alaska 99501 ~ LOCATION O'F WELL 6. LEASE DESIGNATION AND SEP,/AL NO. ?. IF INDIAN, ALLOTTEE OR TRIBE ~ None 8. UNITiFARM OR LEASE NANIE Middle Ground Shoal 9. WELL NO. C-24-23 (Redrill C-11-26) 10. FIELD AND POOL, OR WILDCAT Atsurface Conductor 32, Leg 4 @ 36.53'S and 53.31'E from the center of Leg 1 @ 541.65'N & 1596.41'W from the SE corner Sec. 23, T8N At pro.~sedprod, zone R13W, S.M, ,~0 ~?~$-~,1-~ 1,~'~'~ ~£ ~ *See Below. '"'"' .... · ~ 13. DISTANCE IN MILES AND DIRECTION F-%OM NEAREST TOWN OR'POST OFFICe* 17 miles NW of Kenai., Alaska 14. BOND INFOR1VIATION: State Wide 0il and Gas TYPE Surety and/or NO. TIC- 136503 15. DISTANCE FROM PROPOSED*' -: ~'~' ~,- ' ' ~ ' ~ LOCATION TO NEAREST PROPERTY OR LEASE LINE; ii~.- :" "2500' + (Also to nearest drig, unit, if aDy). :~ . .. {8. DISTANCE FROM PROPOSED ~.OC'A'~IO/%~~ . - ~i. TO NE^~EST WELL D:'--ULLI~a, .COMPLET..mD, OR APPLIE~ FOR, l~r. 1000 '-+ , il6. NO; OF ACR~ IN LEASE 5120 J~B:PROPOSDDE'PT'I-I J ': 9600'±- 21. ELEVATIONS (Show whether DF, RT, C-R, etc.) 105' D.F. MLLW ' ' " PROPOSED 'CASING AN]J'-(JEMENTING PROGRAM Middle Ground Shoal 11. SEC.. T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 23, T8N~ R13W~ S.M. ,.,.~o~ $100,000.00 17. NO. ACRES ASSIGNED TO THiS WELL · 80 20. ROTARY OR CABLE TOOLS Rotary 22.' APPROX. DATE WORK WILL START* November 21, 1968 SIZE OF HOLE SIZE OF CASINGt -WEiGH~ P~R F~ !GlaXO' 'sETTING DEPTH ' qUANTIT, OF CEMEN~ · 15" ~ 10-3/4" 40.5# J 1830' 1300 SaCks (ex±Erin, g), 9-7/8" 7". ..- . .26~&, 29# -N. 9~00'+- 770 Sacks ~'[*~ ~,t/~p --' . ' ::- ,~ L 'i. .... · .- '- , *At top of producing zone: ' 8140'± MD (8000'±:-TVD) 400'±N-& 2490'± E from the SW-corner, Sec. 23, T8N, R13W, S.M. At total depth: 9600'+ MD (9450' + TVD) 6d0'-t~- N'~ 23'2'0'± E from the SW corner, Note: C-11-26 is to be abandoned back to 3600'±. Sect ~~~;N, R13W, S.M. NOV 2 6 proposed new productive zof~e. If Proposal is to drill or deepen direet lonally, give pertinent data on s~bsurface locaitb~'~I~'h're%sured and true vertical dep~_~l~Give.~blowo~preven,.~ program. 24. I hereby certify~~'r~ ' ~ g' rrect ~- S'GNED .~~ - ~-- DAT~ M~X,~rm]~aw !~. 1QAR TIwzmDiv- E×oloitation Engr. (This space for State office use) CONDITIONS OF APPROVAL, IF ANY: [] YES ~No DIR.ECTION/~L SURVEY Iq.EQun~ A.P.L I~C~L CODE P~HT NO ~,-/07 11/27/68 · / DRILLING, CASINa AND ~T.OWOtt~ PF._EVENTTON PROG,~J~M WELL C-24-23 MIDDLE GROUND SHOAL- PLATFORM "C" COOK INLET~ AI~,SKA (REDRILL C- 11-26) 1. Plug and abandon hole (C-11-26) below 3600'+ with cement plugs at permeable formations as required. Set plug at 3600'+ with 200 sacks API class "G" cement, Test 12" 3000 psi preventer stack consisting of double Shaffer gate and G.K. Hydril, riser, and Cameron compact wellhead. 3. Sidetrack hole at 3600'+ and directionally drill 9-7/8" hole to 9600'+. Run logs at TO. Run 9600'+ of 7" 26# and 29# Buttress casing. Cement with 770 sacks API cement. 4. Run 4-1/2" 11,6# N-80 Seal-Lock tubing string equippped with packer. Dis- place Inlet water from casing and tubing with diesel oil, Set packer. Perforate productive zone with 4 shots per foot at selected intervals. Place well on production. PRJ 11-14-68 RECEIVED NOV 2 6 DIVISION OF OI/AND GA~ ANCNORAGE 14 23 23 26 2320' C-23-23 III . C-31-23 · T. 8 N., R. 13 W., S.M. ADL 18756' C-24-23 ~C-43-2 3 II I 23 23 26 13 24 24 25 LOCATION OF CONDUCTOR 3'2, LEG ~ 4 PUBLIC: LAND BO1TOM HOLE LOCATION WELL C'24-23 DESCRIPTION CONDUCTOR 32 , LEG No4 LOCATED 36.53'S AND 53.31'E FROM CENTER OF LEG No 1 CENTER LEG No 1 LOCATED S41.65'NORTH OF THE SOUTH LINE AND 1596.41 WEST OF THE EAST LINE~ 600IN AND 2320'E FROM THE 5W COR, OF SEC,23, T8N, R13W, S.M. SCALE: 1"- 1000' ' LOCATION OF I SHELL-ATLANTIC-STANDARD WELL C'24'23 IN SEC. 23 i