Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation
Commission
HOME
EVENTS
DATA
Data List
Drilling
Production
Orders
Data Miner
Document Search
REPORTS
Reports and Charts
Pool Statistics
FORMS
LINKS
Links
Test Notification
Data Requests
Regulations
Industry Guidance Bulletins
How to Apply
ABOUT US
History
Staff
HELP
Loading...
The URL can be used to link to this page
Your browser does not support the video tag.
Home
My WebLink
About
178-024
AA(� STATE OF ALASKA A OIL AND GAS CONSERVATION COM ION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon El Plug Perforations❑ Fracture Stimulate ❑ Pull Tubing❑ Operations shutdown ❑ Performed: Suspend ❑ Perforate I] Other Stimulate ❑ Alter Casing❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well❑ Other: ❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development 0 Exploratory❑ 178-024 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,AK 99503 50-733-20315-00- 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0018756 MGS C42-23 SEP 1 3 2015 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): Middle Ground Shoal/E,F and G Oil Pools P"'\ 11.Present Well Condition Summary: 1�,1A�1 vs�/ Total Depth measured 9,850 feet Plugs measured N/A feet true vertical 9,303 feet Junk measured N/A feet Effective Depth measured 9,750 feet Packer measured 9,083 feet true vertical 9,208 feet true vertical 8,590 feet Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 2,578' 13-3/8" 2,578' 2,492' * 2,730 psi 1,130 psi Intermediate 8,822' 7-5/8" 8,822' 8,343' 6,890 psi 4,790 psi Production Liner 1,224' 5-1/2" 9,848' 9,301' 7,740 psi 6,390 psi Perforation depth Measured depth 9,155-9,667 feet 1 32017 True Vertical depth 8,656-9,131 feetNWEE) FEB Tubing(size,grade,measured and true vertical depth) 2-7/8" 6.5#/L-80 9,112'(MD) 8,619'(TVD) 9,083'(MD) 315'(MD) Packers and SSSV(type,measured and true vertical depth) HB-BP Perm Pkr 8,590'(ND) Baker TE5 SSSV 315'(ND) 12.Stimulation or cement squeeze summary: Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 26 8 71 672 74 Subsequent to operation: 25 6 131 687 77 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations CI Exploratory❑ Development Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run 0 16.Well Status after work: Oil E] Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR 0 WINJ ❑ WAG ❑ GINJ El 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: 316-284 Contact Dan Marlowe(907)283-1329 Email dmarlowe@hilcorp.com Printed Name Stan W.Golis (--11C. Title Operations Manager Signature �.1 Phone (907)777-8356 Date 1 J t 3 /J.10 t 6.. L(4(. ,/04/6 Form 10-404 Revised 5/2015 RBDMS v L c,t 1 3 2016 Submit Original Only Middle Ground Shoal Well: MGS C42-23 11 SC H E M ATI C Last Completed: 01/24/2013 PTD: 178-024 Hilcorp Alaska,LLC API:50-733-20315-00-00 KB:35' 73'MSL CASING DETAIL Size Wt Grade Conn ID Top Btm 13-3/8" 54.5 K-55 BTC 12.615 Surf 1,765 13-3/8" 61 K-55 BTC 12.515 1,765 2,578 7-5/8" 29.7 N-80 8rnd LTC 6.875 Surf 8,737 13-3/8" 7 5/8" 33.7 N-80 8rnd LTC 6.765 8,737 8,822 5-1/2" 17 N-80 SFJ 4.892 8,624 9,848 TUBING DETAIL 2-7/8" 6.5 L-80 8rd EUE 2.441 Surf 9,112 JEWELRY DETAIL No Depth Depth OD ID Item (MD) (TVD) 1 315' 315' 2.313 Baker TE5 SSSV 1 2 2,089' 2,039' GLM#1 3 3,575' 3,404' GLM#2 4 4,552' 4,296' GLM#3 TOC @+6,642' 5 5,332' 5,036' GLM#4 6 5,856' 5,536' GLM#5 7 6,406' 6,055' GLM#6 8 6,921' 6,540' GLM#7 9 7,469' 7,060' GLM#8 ' 10 7,985' 7,549' GLM#9 11 8,509' 8,045' GLM#10 12 9,029' 8,539' Orifice 13 9,075' 8,582' 2.313 X Nipple 14 9,083' 8,590' HB-BP Perm Packer w/seals 15 9,106' 8,611' 2.205 XN Nipple i- I 16 9,112' 8,617' WL REG XN PERFORATION DETAIL ZI Zone Top(MD) Btm(MD) Top(TVD) Btm FT Date Status X � (TVD) H1 9,155' 9,160' 8,656 8,661' 5' 09/03/16 Open ,01 H2 9,196' 9,215' 8,694' 8,711' 19' H2 9,196' 9,215' 8,694' 8,711' 19' H2 9,215' 9,230' 8,711' 8,725' 15' 09/02/16 Open 7-5/8" , ►' H2 9,260' 9,332' 8,753' 8,820' 72' H2 9,367' 9,503' 8,852' 8,978' 136' H2-H3 9,527' 9,603' 9,000' 9,071' 76' H2-H3 9,604' 9,667' 9,072' 9,131' 63' Top offill _ @ 9,750' 1/20/13 5-u2„ e e PBTD=9,753' TD=9,850' Updated By:AL 09/12/16 • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MGS C42-23 Eline 50-733-20315-00 178-024 9/2/16 9/3/16 Daily Operations: 09/02/16-Friday Arrive OSK heliport. Weather wait. Fly to Platform. Permit to work,Safety meeting&JSA. RU ELU. MU CCL/GR tool suite. Pressure test=250 LO/1500 HI. MU Perf Gun#1(1.75"X 15'GeoDynamics Razor,6 spf,60 deg.). CCL to Top Shot=6.13'. T/IA/OA=75/635/50. RIH with CCL/GR+Perf Gun#1 to 9658'. PUH logging to correlate depths.Shift GR log+22'and repeat log.Send LAS files of correlation log for depth verification. Depth correlation verified,shift-2.0'. Log 9400'-9100'. Return to 9400'. PUH to place shots on depth @ 9208.87'CCL depth (9208.87+6.13'=9215.0'Top Shot). Fire Perf Gun# 1 (1.75"X 15'GeoDynamics Razor,6 spf, 60 deg.) placing perfs @ 9215'-9230'. POOH. T/IA/OA=70/670/50. Return to surface w/shots fired. RD ELU.Secure well,well room and deck. SDFN.Job Ongoing. 09/03/16-Saturday Safety meeting,JSA& Permit to Work. RU ELU. Pressure test=250 LO/1500 HI. MU Perf Gun#2 (1.75"X 5'GeoDynamics Razor,6spf,60 deg.).CCL to Top Shot=4.17'.T/IA/OA=75/630/50. RIH to weight set off and set down @ 9272'. Log up to 9100'to correlate. Shift+29'&repeat to verify depth correction.TIH to 9272'. Log up to place shots on depth at 9150. 83' CCL depth (9150.83'+4.17'=9155.0'Top Shot). Fire Gun perforating 9155'-9160'. Good indication of gun fire at surface. POOH.T/IA/OA=72/650/50. Return to surface w/shots fired. RD ELU. Prep ELU equipment package for boat loadout&return to beach. Fly ELU crew to beach.Job Ended. of TBS, • • yy, sem THE STATE Alaska Oil and Gas Nom►,"i�' �, of LAsKAL Conservation Commission }fit 333 West Seventh Avenue .r GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Stan W. Golis SCANNED SEP 2 8 2016 Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Middle Ground Field, E, F, and G Oil Pools, MGS C42-23 Permit to Drill Number: 178-024 Sundry Number: 316-284 Dear Mr. Golis: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P. oerster Chair DATED this of May, 2016. RBDMS MAY 3 1 2016 • 0 RECEIVED MAY 2 4 2016 STATE OF ALASKA 562-7 / C. ALASKA OIL AND GAS CONSERVATION COMMISSION GCC APPLICATION FOR SUNDRY APPROVALS ���rrr 20 AAC 25.280 1.Type of Request: Abandon El Plug Perforations❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown Suspend ❑ Perforate 0 ' Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other. ❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. Hilcorp Alaska,LLC • Exploratory ❑ Development El , 178-024 3.Address: 3800 Centerpoint Drive,Suite 1400Stratigraphic ❑ Service ❑ 6.API Number. Anchorage,AK 99503 50-733-20315-00-00 " 7.If perforating: 8.WeN Name and Number. What Regulation or Conservation Order governs well spacing in this pool? CO 44 ✓ Will planned perforations require a spacing exception? Yes ❑ No El ✓ MGS C42-23 • 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0018756 , Middle Ground Shoal/E,F and G Oil Pools . 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 9,850 - 9,303 _ 9,750 ' 9,208 • -100 psi N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 2,578' 13-3/8" 2,578' 2,492' 2,730 psi 1,130 psi Intermediate 8,822' 7-5/8" 8,822' 8,343' 6,890 psi 4,790 psi Production Liner 1,224' 5-1/2" 9,848' 9,301' 7,740 psi 6,390 psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 9,196-9,667 , 8,694-9,131 2-7/8" 6.5#/L-80 9,112 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): HB-BP Perm Pkr&Baker TE5 SSSV • 9,083'(MD)8,590'(ND)&315'(MD)315'(ND) 12.Attachments: Proposal Summary 0 Wellbore schematic 0 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development 0- Service ❑ 14.Estimated Date for 15.Well Status after proposed work: 6/7/2016 Commencing Operations: OIL 0 - WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Dan Marlowe(907)283-1329 Email dmartowe@hilcorp.com Printed Name L� Stan 'W.Golis Title Operations Manager "�` ` Signature -� _ A.-' Phone (907)777-8356 Date 51 Z£ ( Zd t 4, COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test El Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes ❑ No CI , RBDMS ' MAY 3 1 2013 Spacing Exception Required? Yes ❑ No ll'kSubsequent Form Required: / f 7 041 / / APPROVED BY / Approved by: � l�- COMMISSIONER THE COMMISSION Date: .'Z7- ft 443 .5 2s11 v s-�4�� �'�,Ql ,� Submit Form and Form 10-403 Revised 11/2015 OpRel GilaNI!vsl r 12 months from th ate of approval. Attachments in Duplicate • • • Well Prognosis Well: C42-23 Hi!corp Alaska,LL( Date: 05/20/2016 Well Name: MGS C42-23 API Number: 50-733-20315-00 Current Status: Gas-Lifted producer Leg: Leg#4 Estimated Start Date: June 07, 2016 Rig: N/A (E-Line) Reg. Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Juanita Lovett (8332) Permit to Drill Number: 178-024 First Call Engineer: Dan Marlowe (907) 283-1329 (0) (907) 398-9904 (M) Second Call Engineer: Trudi Hallett (907) 777-8323 (0) (907) 301-6657 (M) Current Bottom Hole Pressure: 3,600 psi @ 8,000'TVD 0.450 psi/ft SIBP Maximum Expected BHP: 3,600 psi @ 8,000'TVD 0.450 psi/ft SIBP Maximum Potential Surface Pressure: -100 psi Well to be perforated well flowing Brief Well Summary Well Middle Ground Shoal C42-23 is a gas-lifted oil well completed in the Hemlock zone.This project will add Hemlock bench 1&2 sands not currently perforated. E-line Procedure: 1. MIRU E-line, PT lubricator to 1,500 psi Hi 250 Low. 2. RU e-line guns and perforate with well flowing per program. 3. RD E-line. 4. Turn well over to production. Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic Middle Ground Shoal H . • Well: MGS C42-23 • HSCHEMATIC Last Completed: 01/24/2013 PTD: 178-024 Hilcorp Alaska,LLC API:50-733-20315-00-00 KB:35' 73'MSL 1;) ,a; CASING DETAIL },. Size Wt Grade Conn ID Top Btm '" '*/ 13-3/ 8" 54.5 K-55 BTC 12.615 Surf 1,765 I 13-3/8" 61 K-55 BTC 12.515 1,765 2,578 ». 7-5/8" 29.7 N-80 8rnd LTC 6.875 Surf 8,737 13-3/8" '' 7-5/8" 33.7 N-80 8rnd LTC 6.765 8,737 8,822 44M I r>„% 5-1/2" 17 N-80 SFJ 4.892 8,624 9,848 TUBING DETAIL 2-7/8" 6.5 L-80 8rd EUE 2.441 Surf 9,112 • JEWELRY DETAIL No Depth Depth OD ID Item (MD) (TVD) 1 315' 315' 2.313 Baker TES SSSV 2 2,089' 2,039' GLM#1 3 3,575' 3,404' GLM#2 4 4,552' 4,296' GLM#3 roc@±6,642' 5 5,332' 5,036' GLM#4 p 6 5,856' 5,536' GLM#5 7 6,406' 6,055' GLM#6 8 6,921' 6,540' GLM#7 1 9 7,469' 7,060' GLM#8 ' 10 7,985' 7,549' GLM#9 1 11 8,509' 8,045' GLM#10 12 9,029' 8,539' Orifice 13 9,075' 8,582' 2.313 X Nipple .0 14 9,083' 8,590' HB-BP Perm Packer w/seals '.z, 15 9,106' 8,611' 2.205 XN Nipple 16 9,112' 8,617' WL REG XN PERFORATION DETAIL s,. s,R• --'NX Zone Top(MD) Btm(MD) Top(TVD) (Np) FT Date Status .r ,, H2 9,196' 9,215' 8,694' 8,711' 19' t",r, H2 9,196' 9,215' 8,694' 8,711' 19' j H2 9,260' 9,332' 8,753' 8,820' 72' H2 9,367' 9,503' 8,852' 8,978' 136' 7-5/8" 4 ►' H2-H3 9,527' 9,603' 9,000' 9,071' 76' H2-H3 9,604' 9,667' 9,072' 9,131' 63' Topoffill @9,75(Y -' 1/20/13 • 5-1/2" A PBTD=9,753' TD=9,850' Updated By:1LL 05/13/16 Middle Ground Shoal 410 0 Well:MGS C42-23 PROPOSED Last Completed: 01/24/2013 . 'H PTD: 178-024 API:50-733-20315-00-00 Hiker!)Alaska.LLC KB:35' 73'MSL CASING DETAIL 1I Size Wt Grade Conn ID Top Btm i"I 13-3/8" 54.5 K-55 BTC 12.615 Surf 1,765 itki 13-3/8" 61 K-55 BTC 12.515 1,765 2,578 7-5/8" 29.7 N-80 8rnd LTC 6.875 Surf 8,737 13 3/8 7-5/8" 33.7 N-80 8rnd LTC 6.765 8,737 8,822 5-1/2" 17 N-80 SFJ 4.892 8,624 9,848 TUBING DETAIL 2-7/8" 6.5 L-80 8rd EUE 2.441 Surf 9,112 JEWELRY DETAIL 1No Depth Depth OD ID Item (MD) (TVD) 1 315' 315' 2.313 Baker TE5 SSSV 2 2,089' 2,039' GLM#1 3 3,575' 3,404' GLM#2 4 4,552' 4,296' GLM#3 roc@f6saz ;, 5 5,332' 5,036' GLM#4 j40 6 5,856' 5,536' GLM#5 7 6,406' 6,055' GLM#6 8 6,921' 6,540' GLM#7 41 11 4 9 7,469' 7,060' GLM#8 10 7,985' 7,549' GLM#9 .4i: 11 8,509' 8,045' GLM#10 ,. 12 9,029' 8,539' Orifice 13 9,075' 8,582' 2.313 X Nipple 4 14 9,083' 8,590' HB-BP Perm Packer w/seals 4.4 15 9,106' 8,611' 2.205 XN Nipple ' }1 16 9,112' 8,617' WL REG XN ( PERFORATION DETAIL 7. X Zone Top(MD) Btm(MD) Top(TVD) (TVD) FT Date Status x , H1 ±8,955' ±8,965' ±8,470' ±8,480' ±10' Future i;4 � ,, �` H1 ±9,072' ±9,077' ±8,580' ±8,584' ±5' Future H1 ±9,155' ±9,160' ±8,656 ±8,661' ±5' Future H2 9,196' 9,215' 8,694' 8,711' 19' 7-5/8" : H2 9,196' 9,215' 8,694' 8,711' 19' • H2 ±9,215' ±9,230' ±8,711' ±8,725' ±15' Future H2 9,260' 9,332' 8,753' 8,820' 72' H2 9,367' 9,503' 8,852' 8,978' 136' • H2-H3 9,527' 9,603' 9,000' 9,071' 76' i H2-H3 9,604' 9,667' 9,072' 9,131' 63' VA Top of fill @9,750' , 1/20/13 54/2" .A.. ... .. PBTD=9,753' TD=9,850' Updated By:JLL 05/13/16 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon Ll Repair Well L11 Plug Perforations Lj Perforate ✓ Other L✓j Run new gas lift Performed: Alter Casing ❑ Pull Tubing Q Stimulate - Frac ❑ Waiver ❑ Time Extension ❑ siring 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 0 Exploratory ❑ Stratigraphic ❑ Service ❑ 178-024 3. Address: 9127 S Jamaica St, Englewood, CO 80112 6. API Number: 50-733-20315-00-00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 0018756 Middle Ground Shoal C42-23 IRECEIVEE 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): MGS E, F, G Oil Pool AUG 2 9 2013 11. Present Well Condition Summary: G CC Total Depth measured 9,850 feet Plugs measured NA feet true vertical 9,306 feet Junk measured NA feet Effective Depth measured 9,753 feet Packer measured 9,083 feet true vertical 9,161 feet true vertical 8,593 feet Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 2578' 13-3/8" 2578' 2492' 2730 psi 1130 psi Intermediate 8822' 7 5/8" 8822' 8346' 4790 psi 6890 psi Production Liner 1224' 5-1/2" 9848' 9304' 7740 psi 6280 psi Perforation depth Measured depth 9196-9215 feet SCANNED SEP 2 42013 True Vertical depth 8695-9133 feet Tubing (size, grade, measured and true vertical depth) 2-7/8", 6.5#, L-80, ELIE, 8rd; EOT @ 9,112' MD, 8,619' TVD Packers and SSSV (type, measured and true vertical depth) 5" TIW HB -BP Perm Pkr @ 9,083' MD, 8,608' TVD; Baker TE5 SSSV @ 315' MD, 315' TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 34 83 298 520 psi 100 psi Subsequent to operation: 36 121 265 780 psi 100 psi 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory[] Development 0 Service ❑ Stratigraphic ❑ Daily Report of Well Operations yes 16. Well Status after work: Oil ✓ Gas Lj WDSPL GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. 1312-264 Exempt: Contact Sandra Haggard Email Sandra HaggardaMoeneray.com Printed Name Title Regulatory Analyst Signature Phone .. Date �3 v� Form 10-404 Revised 10/2012 T24 ;EfNTEOGY August 26, 2013 Alaska Oil and Gas Conservation Commission Attn: John Norman, Commissioner 333 W. 7 1 Ave., Suite 100 Anchorage, Alaska 99501-3539 Re: Form 10-404, report of sundry well operations Objective: Pull tubing, Repair Well, Perforate and run new gas lift string Middle Ground Shoal # C42-23 Producer Well Middle Ground Shoal Field E, F & G Oil Pool Cook Inlet, Alaska API 50-733-20315-00-00 AUG 29 2013 XTO Energy hereby submits the report of sundry well operations to pull the tubing, repair well, perforate and run new gas lift string. 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, Sandra Haggard, Regulatory Analyst Copy to: Bola Adeyeye, Operations Engineer, Office: 303-397-3606 Daily Activity and Cost Summary_sls ;U f, F , 0iY WPII Name- Middle Ground Shoal C42-23 API/UWI Location Field Name Permit Number State/Province Well Configuration Type 50733203150000 T08N-R13W-S23 Middle Ground Shoal 178-024 Alaska Directional Original KB Elevation (ft) Gr Elev (ft) I KB -Ground Distance (ft) Spud Date i Rig Release Date Total Depth (ttKB) 105.00 0.00 105.00 3/30/1978 5/25/1978 9,850.0 www.xtoenergy.com Page 115 Report Printed: 8125/2073 Job Category COMPLETIONS Primary Job Type / Initial Job Type RECOMPLETION Secondary Job Type / Final Job Type Tbg replacement Start Date 1/4/2013 12:00 End Date 1/25/2013 00:00 Objective Repalce leaking packer, re -perforate, and run new 2-7/8" GL completion Summary Daily O rams Rpt No. 1.0 Report Start Date 1/4/2013 Report End Date 1/5/2013 Operation Summary # 1 1200 Prep to skid rig West. Unload boat with mud products e4ine unit and platform supplies, rig up jacking system, remove storm clamps, and hand rails. Skid rig, trouble shoot jacking system. Remarks # 2 Accept rig at 1200hrs 1-4-13 Costs catch up from rig move leg 2 to leg 4 and 1/2 day for 1-4-13 Construction Summary # 3 Rpt No. 2.0 Report Start Date 1/5/2013 Report End Date 1/6/2013 Operation Summary # 1 0000-2400 Rig Move -Trouble shoot jacking system, replace bad ram cylinder Skid rig West, remove extentions, unable to hook up rams, re -install extentions, pull rig West, square up bottom sub, remove 1 gripper block and rams to put inside to skid rig North, East side gripper blew seal, replace seal, upper section needs to be moved North aprox 4" work to square up top section and pull North. Replace hand rails after rig moves. Remarks # 2 7 hours down time working on jacking system. Construction Summary # 3 Rpt No. Report Start Date Report End Date Operation Summary # 1 3.0 1/6/2013 1/7/2013 0000 / Work on jack system, Center rig over C42-23 0300 / Prep pits and weight up fluid to 9.8 ppg (535 bbis), install storm clamps on rig, rig down rig jacks, set cat walk, finish hand rails, pick up tools and clean up in cellar. Prep for back load 1200 / Hang and make up 10", 6" and 4" flow lines, from rig to pits make up high pressure mud line, cleaning up cellar, wellhead room, and prep for backload, function test flow lines, no leaks, pressure test HP mud line 3000 psi, good test. 2000 / Well 70 psi tubing (header pressure) and 200 psi on annulus, shut in well. Remove gas lines from annulus, and make up circ lines, make up circ line to tubing. 2230 / PJSM, Pump 9.8 ppg down tubing with returns to production, 2.5 bpm, 50 psi (got returns @ 140 bbls pumped) Remarks# 2 0300 - 0900 rig up slick line test lube, run #1 - 2.5" full drift scratcher to 9715' WLM tag fill run #2 - pull orifice from GLV #11 8356' Rig down slick line (see wireline report 1-6-13). Production shut down gas lift and start bleeding down annulus after run #1 and leave tubing open to production header. Construction Summary # 3 www.xtoenergy.com Page 115 Report Printed: 8125/2073 Daily Activity and Cost Summary_sls t�:tHc;Y Well Name: Middle Ground Shoal C42-23 API/UWI Location Field Name Perrot Number State/Province Well Configuration Type 50733203150000 T08N-R13W-S23 Middle Ground Shoal 178-024 Alaska Directional Original KB Elevation (ft) Gr Elev (ft) KB -Ground Distance (ft) !Spud Date Rig Release Date Total Depth (ftKB) 105.00 0.00 105.00 3/30/1978 5/25/1978 9,850.0 Daflv Op erations� Rpt No. Report Start Date Report End Date Operation Summary # 1 4.0 1/7/2013 1/8/2013 0000 / Pump 9.8 ppg fluid down tubing, monitor returns to production 9.7+ returns with 390 bbis pumped, shut down pump 0100 / Monitor well flow ann built 60 psi, tbg static, 0130 / Pump additional 5 bbis to production, 9.6 ppg returns with gas breaking out, shut down,) ine up and pump with returns to through choke to pits, weight up returns. 3 bpm, 400 psi 0300 / Monitor well - Static to slight vacuum 0330 / Blow down and rig down circ lines 0400 / Set BPV, nipple down tree, remove tree. 0700 / Installing fitting on side of neck of hanger for SSSV measurements showed hanger would not fit through 7-1/16" DSA with out breaking fitting, Confer with town and discuss options. (Cameron, Slick line, and engineer) 0830 / Moblize E -line crew, set down and nipple up tree, test tree and hanger void 5000 psi 0930 / Wait on a -line crew. Monitor well on vacuum.Clean celler and organize decks. 1200 / Rig up E -line. test lube 1500 psi, 1730 / RIH with 2.25 jet cutter locate and cut below X nigple-ql5fiLpOOH with tools. 2100 un temporary IOCKOUT sleeve in SSSV 297', rig down wire line. 2130 / Fill well with 44 bbis (2.4 bph) 2200 / Set BPV, nipple down tree. Remarks # 2 Correlate with Pollard's pressure & temperature survey down pass enlarged dated Aug 25, 2011 Construction Summary # 3 Rpt No. Report Start Date Report End Date Operation Summary # 1 5.0 1/8/2013 1/9/2013 0000 / Install riser and DSA nipple up BOPS _ 1100 M/U test joint & test BOPs 2100 Install drig nipple 2330 M/U Landing joint Remarks # 2 Construction Summary # 3 Rpt No. Report Start Date Report End Date Operation Summary # 1 6.0 1/9/2013 1/10/2013 0000 Pull & UD Hanger, Up wt. 97k 0100 Monitor well, Mix & pump slug 0300 UD 3-1/2" Tbg, checking for NORM, Tbg cut in collar Remarks # 2 Tbg cut @ 9154', 1/8" from top of collar, OD of collar too big for overshot, ID too small for spear Construction Summary # 3 Rpt No. Report Start Date Report End Date Operation Summary # 1 7.0 1/10/2013 1/11/2013 0000 Set wear ring 0100 M/U Junk mill & motor assembly & RIH 1100 Mill fish f/ 9,167'- U 9,168.5' Up wt. 125k, Dn. wt. 92k, 1700 psi @ 108 gpm, cut mud wt. to 9.7 ppg 1200 Circ., cont. cut mud wt. to 9.7 ppg 1330 POOH & UD mill & motor 1930 M/U Overshot & RIH Remarks # 2 Mill showed signs of milling collar & tbg Construction Summary # 3 www.xtoonergy.com Page 215 Report Printed: 8/26/2013 MGS C42-23 Cook Inlet, Alaska Leg 4, Conductor 25 API No.: 50-733-20315 Spud: 3.13-78 Surf Csg: 13 3/8", 54.5/61 Ib, K55. Set @ 2,578'. Cmt w/ 2,100 sx. Intermediate Csg: 7 518" 29.7133.7 Ib, N80. Set @ 8,822'. Cmt wl 450 sx. TOC @ ±6,642'. Prod Liner: 5-1/2", 17 Ib, N80. Set @ 9,848'. TOL @ 8,624'. Cmt w/ 210 sx. Sqz TOL w/ 150 sx. #1 2089 2041 12 942 1 100C #2 3575 3406 12 922 962 #3 4552 4298 12 902 936 #4 5332 5037 12 883 905 #5 5856 5537 12 864 886 #6 1 6406 6057 14 834 863 #7 6921 6541 14 814 1 843 #8 7469 7061 14 792 821 #9 7985 7551 14 769 798 #10 8509 8047 14 744 772 #11 9029 8541 14 Orifice FILL: None (10-30-10) PBTD: 9,753' MD (9,161' TVD) TD: 9,850' MD (9,306' TVD) CURRENT COMPLETION ACB 03-04-13 KB: 35' Water Depth: 73' MSL ALL TBG IS 2-7/8" 6.5# L80 8RD EUE 4' Pup A 2-7/8" 6.5# L80 8rd EUE @ 309' 2-7/8" Baker TE5 SSSV (2.313" ID) @ 315' 4' Pup A 2-718" 6.5# L80 8rd EUE @ 321' 282 Jts 2-7/8"6.5# L80 8rd EUE 4' Pup Jt 2-718" 6.5# L80 8rd EUE @ 9,071' 2-7/8" X Nipple (2.313" ID) 8rd 9Cr @ 9,075' 6' Pup A 2-718" 6.5# L80 8rd EUE @ 9,076' TIW Anchor w/ Seals @ 9,082' 5'/2" TIW HB -BP Perm Pkr L80 @ 9,083' 10' MOE L80 @ 9,089' X -over MOE to 2-7/8" L80 8rd @ 9,099' 6' Pup Jt 2-7/8" 6.5# L80 8rd EUE @ 9,100' 2-718" XN Nipple (2.205" ID) 8rd 9Cr @ 9,106' 4' Pup Jt 2-718" 6.5# L80 8rd EUE @ 9,107' WL REG @ 9,112 - GR -GS- 8,654'& 8,689' (2 holes) SQZ'd wl 70 sk on 4-25-05. H K -H N: 9,196'-9,215' HK -HN: 9,260'-9,332' HN -HR: 9,367'-9,503' HR -HZ: 9,527'-9,603' HR -HZ: 9,604'-9,667' STATE OF ALASKA AL O IL AND GAS CONSERVATION COM•ION REPORT OF SUNDRY WELL OPERATIONS AOGCC 1. Operations Abandon L] Repair Well U Plug Perforations ❑ Perforate 0 Other U Performed: Alter Casing ❑ Pull Tubing 0 Stimulate - Frac ❑ Waiver ❑ Time Extension ❑ 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 El Exploratory ❑ 178 -024 - 3. Address: 9127 S Jamaica Street Stratigraphic ❑ Service ❑ 6. API Number: Englewood, CO 80112 50- 733 -20315 * DO 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 0018756 - Middle Ground Shoal C42 -23 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): _ N/A MGS E, F, G Oil Pools 11. Present Well Condition Summary: Total Depth measured 9,850 feet Plugs measured NA feet true vertical 9,306 feet Junk measured NA feet Effective Depth measured 9,753 feet Packer measured 9,112 feet true vertical 9,161 feet true vertical 8,618 feet Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 2,578' 13 -3/8" 2,578' 2,492' 2,730 psi 1,130 psi Intermediate 8,822' 7 -5/8" 8,822' 8,346' 4,790 psi 6,890 psi Production Liner 1,224' 5 -1/2" 9,848' 9,304' 7,740 psi 6,280 psi Perforation depth Measured depth 9,196 - 9,667 feet SCANNED MAR 2 7 2013 True Vertical depth 8,697 - 9,134 feet Tubing (size, grade, measured and true vertical depth) 2 -7/8 ", 6.5#, L80, 8rd, EUE tbg EOT @ 9,112' MD, 8,618' TVD Packers and SSSV (type, measured and true vertical depth) TIW HB -BP Perm. Pkr. @ 9,083' MD, 8,592' TVD; Baker TE -5 SSSV © 315' MD, 315' TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 40 30 300 600 psi 100 psi Subsequent to operation: 35 30 265 770 psi 100 psi 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run N/A Exploratory Development is r Service ❑ Stratigraphic ❑ Daily Report of Well Operations yes 16. Well Status after work: s Oil 0 Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ 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 -264 Contact Sandra Haggard Email sandra haggardt xtoenergy.com i Printed Name ..5:74fo(/,0;60 "04.�� Title Regulatory Analyst Signature i. /�,.." 4 .9" i ae • Phone 303 - 397 -3672 Date , j'% /, ea d or Form 10-404 Revised 10 /2012RBDMS MAR 2 2 2013,20 f Submit Original Only • • ;(1.0 AoGcr March 21, 2013 Alaska Oil and Gas Conservation Commission Attn: John Norman, Commissioner 333 W. 7 Ave., Suite 100 Anchorage, Alaska 99501 -3539 RE: Submission of Report 10 -404 for Well Operations for MGS C42 -23 Dear Mr. Norman, XTO Energy, Inc. hereby submits the Report of Sundry Well Operations Form 10 -404 for the MGS C42 -23 Please find enclosed the following information for your records: 1. Form 10 -404 Report of the Sundry Well Operations 2. Daily Operations Report 3. Current Wellbore Schematic If you require additional information, please contact me at (303) 397 -3672 Sincerely, Sandra M. Haggard Regulatory Analyst, Western Division CC: Alec Bridge, Operations Engineer @ (303) 397 -3608 Scott Griffith Scott Landon XTO Energy Inc. • P.O. Box 6501 • Englewood, CO 80155 • 9127 S. Jamaica St. • Englewood, CO 80112 • (303) 397 -3600 • Fax: (303) 397 -3899 An ExxonMobil Subsidiary • 0 TO ACB 03 -04 -13 E NERGY CURRENT COMPLETION KB: 35' �// Water Depth: 73' MSL MGS C42 -23 L Cook Inlet, Alaska A Leg 4, Conductor 25 ALL TBG IS 2 -7/8" 6.5# L80 8RD EUE • API No.: 50- 733 -20315 4 Spud: 3-13-78 0 4' Pup Jt 2 -7/8" 6.5# L80 8rd EUE @ 309' 9 2 -7/8" Baker TE5 SSSV (2.313" ID) @ 315' 4' Pup Jt 2 -7/8" 6.5# L80 8rd EUE @ 321' 282 Jts 2- 7/8 "6.5# L80 8rd EUE Surf Csg: 13 3/8 ", 54.5/61 lb, K55. 4' Pup Jt 2 -7/8" 6.5# L80 8rd EUE @ 9,071' Set @ 2,578'. Cmt w/ 2,100 sx. 2 -7/8" X Nipple (2.313" ID) 8rd 9Cr @ 9,075' 6' Pup Jt 2 -7/8" 6.5# L80 8rd EUE @ 9,076' TIW Anchor w/ Seals @ 9,082' 5 -' /2" TIW HB -BP Perm Pkr L80 @ 9,083' 10' MOE L80 @ 9,089' 7 ;/ X -over MOE to 2 -7/8" L80 8rd @ 9,099' Intermediate Csg: 7 5/8" 29.7/33.7 Ib, 6' Pup Jt 2 -7/8" 6.5# L80 8rd EUE @ 9,100' N80. Set @ 8,822'. Cmt w/ 450 sx. /r 2 -7/8" XN Nipple (2.205" ID) 8rd 9Cr @ 9,106' TOC @ ±6,642'. 4' Pup Jt 2 -7/8" 6.5# L80 8rd EUE @ 9,107' iir WL REG @ 9,112' 0 oil I %0, GR -GS: 8,654' & 8,689' (2 holes Liner: Prod 1 1 " f SQZ'd w/ 70 sk on 4- 25 -05. � � 1 1 11 Set @ 9,848' TOL @ 8,624'. r % Cmt w/ 210 sx. Sqz TOL w/ 150 sx. HK-HN: 9,196' 9,215' 00 #1 2089 2041 12 942 1000 #2 3575 3406 12 922 962 roor HK -HN: 9,260'- 9,332' #3 4552 4298 12 902 936 0 #4 5332 5037 12 883 905 o e #5 5856 5537 12 864 886 , _. — HN -HR: 9,367'- 9,503' #6 6406 6057 14 834 863 l } #7 6921 6541 14 814 843 / ' HR -HZ: 9,527'- 9,603' #8 7469 7061 14 792 821 0 #9 7985 7551 14 769 798 HR -HZ: 9,604'- 9,667' #10 8509 8047 14 744 772 ol K #11 9029 8541 14 Orifice FILL: None (10- 30 -10) � js�'�Zif 1 . PBTD: 9,753' MD (9,161' ND) TD: 9,850' MD (9,306' ND) To Saily Activity and Cost Summary. ENERGY Well Name: Middle Ground Shoal C42 -23 API /UWI Location Field Name Permit Number State Well Configuration Type 50733203150000 TO8N- R13W -S23 Middle Ground Shoal 178 -024 Alaska Original KB Elevation (ft) Ground Elevation (ft) KB- Ground Distance (ft) Spud Date Rig Release Date Total Depth (ftKB) 105.00 0.00 105.00 3/30/1978 5/25/1978 9,850.0 Jobs Job Category Primary Job Type / Initial Job Type Secondary Job Type / Final Job Type Start Date End Date Well Maintenance Slickline 1/6/2013 00:00 1/6/2013 00:00 Objective Pre - Workover prep - Drift run - Pull # 11 orifice valve Summary Daily Operations Rpt No. Report Start Date Report End Date Operation Summary # 1 1.0 1/6/2013 1/7/2013 - Rig up wireline and pressure test lubricator. - Run in hole with 2 -1/2" full drift scratcher. Tools did not sit down but we did see bobbles on weight indicator going through isolation packer assembly at 9264' / 9286' / 9300' / 9340' / 9346' all depths WLM. Continue down hole out end of tubing and tag fill at 9715' WLM / 9750' MD. Pull out of hole. - Run in hole with 3 -1/2" OK -6 KOT & ML pulling tool to # 11 GLM at 8367' WLM. Had trouble locating pocket but was able to finally latch & pull 5/16" orifice valve. Pull out of hole. - Rig down wireline & turn well over to drilling. Remarks # 2 Construction Summary # 3 www.xtoenergy.com Page 1/1 Report Printed: 3/13/2013 j tro •wily Activity and Cost Summary. ENERGY Well Name: Middle Ground Shoal C42 -23 API /UWI Location Field Name Permit Number State Well Configuration Type 50733203150000 T08N- R13W -S23 Middle Ground Shoal 178 -024 Alaska Original KB Elevation (ft) Ground Elevation (ft) IKB- Ground Distance (ft) Spud Date Rig Release Date Total Depth (ftKB) 105.00 0.00 j 105.00 3/30/1978 5/25/1978 9,850.0 Jobs Job Category Primary Job Type / Initial Job Type Secondary Job Type / Final Job Type Start Date End Date COMPLETIONS RECOMPLETION Tbg replacement 1/4/2013 12:00 1/25/2013 00:00 Objective Repalce leaking packer, re- perforate, and run new 2 -7/8" GL completion Summary Daily Operations Rpt No. Report Start Date Report End Date Operation Summary # 1 1.0 1/4/2013 1/5/2013 1200 Prep to skid rig West. Unload boat with mud products a -line unit and platform supplies, rig up jacking system, remove storm clamps, and hand rails. Skid rig, trouble shoot jacking system. Remarks # 2 Accept rig at 1200hrs 1 -4 -13 Costs catch up from rig move leg 2 to leg 4 and 1/2 day for 1-4 -13 Construction Summary # 3 Rpt No. Report Start Date Report End Date Operation Summary # 1 2.0 1/5/2013 1/6/2013 0000 -2400 Rig Move - Trouble shoot jacking system, replace bad ram cylinder Skid rig West, remove extentions, unable to hook up rams, re- install extentions, pull rig West, square up bottom sub, remove 1 gripper block and rams to put inside to skid rig North, East side gripper blew seal, replace seal, upper section needs to be moved North aprox 4" work to square up top section and pull North. Replace hand rails after rig moves. Remarks # 2 7 hours down time working on jacking system. Construction Summary # 3 Rpt No. Report Start Date Report End Date Operation Summary # 1 3.0 1/6/2013 1/7/2013 0000 / Work on jack system, Center rig over C42 -23 0300 / Prep pits and weight up fluid to 9.8 ppg (535 bbls), install storm clamps on rig, rig down rig jacks, set cat walk, finish hand rails, pick up tools and clean up in cellar. Prep for back load 1200 / Hang and make up 10 ", 6" and 4" flow lines, from rig to pits make up high pressure mud line, cleaning up cellar, wellhead room, and prep for backload, function test flow lines, no leaks, pressure test HP mud line 3000 psi, good test. 2000 / Well 70 psi tubing (header pressure) and 200 psi on annulus, shut in well. Remove gas lines from annulus, and make up circ lines, make up circ line to tubing. 2230 / PJSM, Pump 9.8 ppg down tubing with returns to production, 2.5 bpm, 50 psi (got returns © 140 bbls pumped) Remarks # 2 0300 - 0900 rig up slick line test lube, run #1 - 2.5" full drift scratcher to 9715' WLM tag fill run #2 - pull orifice from GLV #11 8356' Rig down slick line (see wireline report 1- 6 -13). Production shut down gas lift and start bleeding down annulus after run #1 and leave tubing open to production header. Construction Summary # 3 www.xtoenergy.com Page 1/5 Report Printed: 3/13/2013 � ro •al Activity and Cost Summary. ERGY Well Name: Middle Ground Shoal C42 -23 API /UWI Location Field Name Permit Number State Well Configuration Type 50733203150000 TO8N- R13W -S23 Middle Ground Shoal 178 -024 Alaska Original KB Elevation (ft) Ground Elevation (ft) KB- Ground Distance (ft) Spud Date Rig Release Date Total Depth (ftKB) 105.00 0.00 105.00 3/30/1978 5/25/1978 9,850.0 Daily Operations Rpt No Report Start Date Report End Date Operation Summary # 1 4.0 1/7/2013 1/8/2013 0000 / Pump 9.8 ppg fluid down tubing, monitor returns to production 9.7+ returns with 390 bbls pumped, shut down pump 0100 / Monitor well flow ann built 60 psi, tbg static, 0130 / Pump additional 5 bbls to production, 9.6 ppg returns with gas breaking out, shut down,l ine up and pump with returns to through choke to pits, weight up returns. 3 bpm, 400 psi 0300 / Monitor well - Static to slight vacuum 0330 / Blow down and rig down circ lines 0400 / Set BPV, nipple down tree, remove tree. 0700 / Installing fitting on side of neck of hanger for SSSV measurements showed hanger would not fit through 7- 1/16" DSA with out breaking fitting, Confer with town and discuss options.(Cameron, Slick line, and engineer) 0830 / Moblize E -line crew, set down and nipple up tree, test tree and hanger void 5000 psi 0930 / Wait on a -line crew. Monitor well on vacuum.Clean celler and organize decks. 1200 / Rig up E -line. test lube 1500 psi, 1730 / RIH with 2.25 jet cutter locate and cut below X nipple 9156' POOH with tools. 2100 / Run temporary lockout sleeve in SSSV 297, rig down wire line. 2130 / Fill well with 44 bbls (2.4 bph) 2200 / Set BPV, nipple down tree. Remarks # 2 Correlate with Pollard's pressure & temperature survey down pass enlarged dated Aug 25, 2011 Construction Summary # 3 Rpt No. Report Start Date Report End Date Operation Summary # 1 5.0 1/8/2013 1/9/2013 0000 / Install riser and DSA, nipple up BOPs 1100 M/U test joint & test BOPs 2100 Install drlg nipple 2330 M/U Landing joint Remarks # 2 Construction Summary # 3 Rpt No Report Start Date Report End Date Operation Summary # 1 6.0 1/9/2013 1/10/2013 0000 Pull & UD Hanger, Up wt. 97k 0100 Monitor well, Mix & pump slug 0300 UD 3 -1/2" Tbg, checking for NORM, Tbg cut in collar Remarks # 2 Tbg cut © 9154', 1/8" from top of collar, OD of collar too big for overshot, ID too small for spear Construction Summary # 3 Rpt No. Report Start Date Report End Date Operation Summary # 1 7.0 1/10/2013 1/11/2013 0000 Set wear ring 0100 M/U Junk mill & motor assembly & RIH 1100 Mill fish f/ 9,167' - t/ 9,168.5' Up wt. 125k, Dn. wt. 92k, 1700 psi @ 108 gpm, cut mud wt. to 9.7 ppg 1200 Circ., cont. cut mud wt. to 9.7 ppg 1330 POOH & UD mill & motor 1930 M/U Overshot & RIH Remarks # 2 Mill showed signs of milling collar & tbg Construction Summary # 3 www.xtoenergy.com Page 2/5 Report Printed: 3/13/2013 ) ( TO •wily Activity and Cost Summary. ENERGY Well Name: Middle Ground Shoal C42 -23 API /UWI Location Field Name Permit Number State Well Configuration Type 50733203150000 TO8N- R13W -S23 Middle Ground Shoal 178 -024 Alaska Original KB Elevation (ft) Ground Elevation (ft) KB- Ground Distance (ft) Spud Date Rig Release Date Total Depth (ftKB) 105.00 0.00 105.00 3/30/1978 I 5/25/1978 9,850.0 Daily Operations Rpt No. Report Start Date Report End Date Operation Summary # 1 8.0 1/11/2013 1/12/2013 0000 Cont. RIH w/ Overshot t/ 9,116' 0430 Cut & slip drlg line 0600 Latch onto fish @ 9,168', Up wt. 120k, Dn. wt. 92k, Rot. wt. 105k, 500 psi @ 80 gpm, K- Anchor parted w/ 5k over -pull 0700 Mix & pump slug, Monitor well 0800POOH, Retrieved 5.10' of fish 1430 Service rig 1530 M/U Pkr mill assembly & RIH t/ 9,162', Break circ. @ 3,000' & 6,000' Remarks # 2 K- Anchor parted w/ 5k over -pull, Retrieved pup joint & 0.50' of K- Anchor, Construction Summary # 3 Rpt No. Report Start Date Report End Date Operation Summary # 1 9.0 1/12/2013 1/13/2013 0000 Mill on Pkr f/ 9,173' - t/ 9174.5' , Up wt. 122k, Dn. wt. 95k, 1500psi @ 110 gpm. 1700 Circ. out gas 1800 Mill on Pkr © 9,174.5' Remarks # 2 Construction Summary # 3 Rpt No. Report Start Date Report End Date Operation Summary # 1 10.0 1/13/2013 1/14/2013 0000 Repair leak in Hi- pressure mud line 0100 POOH, LID mill & motor 0530 M/U new mill & motor, RIH 1200 Mill on Pkr f/ 9,174.5' - t/ 9176' 1600 Circ Hi -Vis sweep 1830 POOH Remarks # 2 Construction Summary # 3 Rpt No. Report Start Date Report End Date Operation Summary # 1 11.0 1/14/2013 1/15/2013 0000 POOH & UD mill & motor 0200 M/U spear for 2.5" ID & RIH 0230 Trouble shoot draw -works traction motors 0300 Cont. RIH 0730 Tag fish @ 9,177', attempt to spear fish 0800 CBU, small amount of gas, monitor well 1200 POOH, no fish 1900 Pull wear ring 1930 Test BOPs Remarks # 2 Construction Summary # 3 Rpt NO Report Start Date Report End Date Operation Summary # 1 12.0 1/15/2013 1/16/2013 0000 Test BOPS 0600 M/U spear for 2.992" I.D. & RIH 1030 Tag fish @ 9,177', could not catch fish 1100 POOH 1830 M/U 3 -1/4" Taper Tap & RIH Remarks # 2 Construction Summary # 3 www.xtoenergy.com Page 3/5 Report Printed: 3/13/2013 • ) fro •ally Activity and Cost Summary. ENERGY Well Name: Middle Ground Shoal C42 -23 API /UWI Location Field Name Permit Number State Well Configuration Type 50733203150000 TO8N- R13W -S23 Middle Ground Shoal 178 -024 Alaska Original KB Elevation (ft) Ground Elevation (ft) KB- Ground Distance (ft) Spud Date ; Rig Release Date Total Depth (ftKB) 105.00 0.00 105.00 3/30/1978 j 5/25/1978 9,850.0 Daily Operations Rpt No. Report Start Date Report End Date Operation Summary # 1 13.0 1/16/2013 1/17/2013 0000 Screw into fish w/ taper tap, attempt to work fish free, jar with 20k over 0100 POOH & UD Taper tap 0830 Service rig 0930 M/U mill assembly & RIH 1600 Mill on packer & MOE f/ 9177 - t/ 9180' 2200 Circ. Hi -Vis sweep Remarks # 2 Construction Summary # 3 Rpt No. Report Start Date Report End Date Operation Summary # 1 14.0 1/17/2013 1/18/2013 0000 POOH & UD mill & motor 0500 Service rig 0530 M/U 3.032" spear for MOE & RIH 0930 Spear fish and jar free, Up wt 120k, Dn wt 95k, jarring @ 30k over, Pulled free @ 180k 1100 CBU 1300 POOH & UD fish, retrieved @ 180' 1730 M/U Pkr mill assembly & RIH Remarks # 2 Construction Summary # 3 Rpt No. Report Start Date Report End Date Operation Summary # 1 15.0 1/18/2013 1/19/2013 0000 Cont. RIH w/ Pkr mill assembly t/ 9,170' 0100 Wash f/ 9,170' - t/ 9,359' 0300 Mill on Pkr f/ 9,359' - t/ 9,361' & push t/ 9,393', Lost 400 psi on string, Up wt 120k, Dn wt 95k, 2600 psi @ 118 gpm 0630 Drop ball to open circ sub, did not see circ sub open, Circ out gas & monitor well 0830 POOH looking for wash -out, UD mill assembly 1430 M/U Spear assembly & RIH t/ 9,359 2030 Wash and push Pkr t/ 9,650' 2300 Circ. Hi -Vis sweep Remarks # 2 Construction Summary # 3 Rpt No. Report Start Date Report End Date Operation Summary # 1 16.0 1/19/2013 1/20/2013 0000 Cont. circ Hi -Vis sweep 0130 Spear fish @ 9,650' 0200 POOH & UD fish, Retrieved 19.60' 0830 M/U clean -out assembly & RIH tagged fill @ 9,657' 1730 Wash f/ 9,657' - t/ 9,750', 5 -1/2" Csg Scraper t/ 9,207' 2000 Circ Hi -Vis sweep to 7 -5/8" Csg, Spot 9.7ppg filtered (2 micron) brine f/ 9,750' - t/ 8,600' 2200 POOH t/ 9,000' 2230 Open circ. sub, Circ. 20 bbl Hi -Vis sweep, 2800 psi @ 180 gpm Remarks # 2 Put # 7 Cat on line Construction Summary # 3 Rpt No. Report Start Date Report End Date Operation Summary # 1 17.0 1/20/2013 1/21/2013 0000 Cont. circ. Hi -Vis sweep @ 9,000' thru circ. sub, 2800 psi © 180 gpm 0200 POOH & UD Clean -out assembly - part of the mill missing 0700 Remove Drlg Nipple & N/U Shooting Flange 1030 R/U Pollard Wireline 1200 PJSM & Run Perf Guns, 2 spf @ 120 degree phasing on 3 -3/8" guns Run #1 9,631' - 9,667' Run #2 Misfire Run #3 9,604' - 9,631' Run #4 9,567' - 9,603' Remarks # 2 Construction Summary # 3 www.xtoenergy.com Page 4/5 Report Printed: 3/13/2013 ) fro •aily Activity and Cost Summary. E NERGY Well Name: Middle Ground Shoal C42 -23 API /UWI Location Field Name Permit Number State Well Configuration Type 50733203150000 TO8N- R13W -S23 Middle Ground Shoal 178 -024 Alaska Original KB Elevation (ft) Ground Elevation (ft) KB- Ground Distance (ft) Spud Date Rig Release Date Total Depth (ftKB) 105.00 0.00 105.00 3/30/1978 5/25/1978 9,850.0 Daily Operations Rpt No. Report Start Date Report End Date Operation Summary # 1 18.0 1/21/2013 1/22/2013 0000 Cont. Run Perf Guns, 2 spf © 120 degree phasing on 3 -3/8" guns Run #5 9,531' - 9,567' Run #6 9,527' - 9,531' / Run #7 9,467' - 9,503' Run #8 9,431' - 9,467' Run #9 9,395' - 9,431' Run #10 9,367' - 9,395' 275' Net footage w/ 550 totaF1 oles R/D Wireline 1200 Remove shooting flange & install drlg nipple 1400 UD drillpipe Remarks # 2 Construction Summary # 3 Rpt No. Report Start Date Report End Date Operation Summary # 1 19.0 1/22/2013 1/23/2013 0000 Cont. lay down drillpipe drill collars 1000 Pull ware ring 1100 Test BOPE 250/5000 psi, annular 220/2500 psi., Koomey performance test, test rig gas alarms (Witness waived by Mr. Jim Regg ofAOGCC) 1800 Rig up to run completion, PJSM 1900 Work on power tongs Remarks # 2 Construction Summary # 3 Rpt No Report Start Date Report End Date Operation Summary # 1 20.0 1/23/2013 1/24/2013 0000 Run 2 -7/8" Completion 1030 Spot 20 bbl Packer fluid 1200 Land Tbg hanger, Run in lock -downs 13.11 Lop_ far. Testtivil ei Plum/ 1000.3)si. Pic 9 R ',.1[1 LEG 1400 Safety stand -down 1600 Test Casing t/ 200 psi 2030 UD landing joint -y 2100 N/D BOPs Remarks # 2 See attached WBD for completion details Construction Summary # 3 Rpt No. Report Start Date Report End Date Operation Summary # 1 • 21.0 1/24/2013 1/25/2013 0000 Cont. N/D BOPs 0200 N/U Tree & test t/ 5000 psi, OK 0830 Rig up Wireline and retieve bar and plug body, working boat and preparring for rig skid 1800 Skid rig and inject trash mud from pits 0000 Rig released from C 42 -23 to C 24 -23 Remarks # 2 Construction Summary # 3 Rpt No. Report Start Date Report End Date Operation Summary # 1 22.0 1/25/2013 1/26/2013 Remarks # 2 Construction Summary # 3 www.xtoenergy.com Page 5/5 Report Printed: 3/13/2013 ) (TO aily Activity and Cost Summary. ENERGY Well Name: Middle Ground Shoal C42 -23 API /UWI Location Field Name Permit Number State Well Configuration Type 50733203150000 TO8N- R13W -S23 Middle Ground Shoal 178 -024 Alaska Original KB Elevation (ft) Ground Elevation (ft) KB- Ground Distance (ft) Spud Date Rig Release Date Total Depth (ftKB) 105.00 0.00 105.00 3/30/1978 5/25/1978 9,850.0 Jobs Job Category Primary Job Type / Initial Job Type Secondary Job Type / Final Job Type Start Date End Date Well Maintenance Slickline 1/24/2013 00:00 1/24/2013 00:00 Objective Post workover pull RHCP plug Summary Daily Operations Rpt No. Report Start Date Report End Date Operation Summary # 1 1.0 1/24/2013 1/24/2013 - Rig up wireline and pressure test lubricator. - Run in hole with 2" JDC pulling tool to 9086' WLM. Latch & pull RHCP prong. Pull out of hole. - Run in hole with 2 -1/2" GR pulling tool to 9089' WLM. Latch & pull RHCP plug body. Pull out of hole. - Rig down wireline. Remarks # 2 Construction Summary # 3 i www.xtoenergy.com Page 1/1 Report Printed: 3/13/2013 • • AG CA- Z - Z3 Regg, James B (DOA) 6,00 From: Alaska_Drilling @xtoenergy.com Sent: Monday, January 07, 2013 3:56 PM J i To: Regg, James B (DOA) t I Subject: Platform C Status C Mr. Regg, We had nippled down tree and pulled it off of C 42 -23, the outlet for the SSSV control line was on the outside of hanger neck. With fitting screwed in we would not have enough space in 7 -1/16 X 13 -5/8 DSA to pull out without damaging fitting causing SSSV to close. We re -set and nippled up tree, and tested tree and hanger void. We mobilized E -line crew and are rigging up to cut tubing above top packer, we will then run sleeve in SSSV locking it open. WE will re- install BPV and nipple down tree. Nipple up BOPE, and estimate testing late Tuesday night or early Wednesday morning. 1 7 I will up date you in the morning to tell you our status. Thanks Brad Rasch Platform C 907 - 776 -2534 • • 0[ ALAEKKA kU L SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION CO11I11LIISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276-7542 Maria Perez Regulatory Analyst J $ — 0c2 XTO Energy, Inc. k 200 N. Loraine, Suite 800 Midland, TX 79701 Re: Middle Ground Shoal Field, E, F, 8s G Oil Pool, MGS #C42 -23 Sundry Number: 312 -264 Dear Ms. Perez: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. Commissioner DATED this 4.1 day of August, 2012. Encl. • RECEIVED JUL 1 8 )(TO ECEI ENERGY 202 a subsidiary of ExxonMobil AOGCC July 17, 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 tbg, mill out pkrs, perforate, and run new gas lift string. Middle Ground Shoal #C42 -23 Production Well Middle Ground Shoal Field, E, F, & G Oil Pool Cook Inlet, Alaska API 50-733-20315-00-00 XTO Energy Inc. hereby submits its Application for Sundry Approval to pull tbg, mill out pkrs, perforate, and run new gas lift string. Enclosed are the following attachments: 1. Form 10 -403 Application for Sundry Approval. 2. Cover Page 3. Summary Page. 4. Production Plot 5. Sub Surface Safety Valve Report 6. Deviation Survey. 7. Job Procedure. 8. Current Wellbore Diagram. 9. Proposed Wellbore Diagram. 10. Wellhead Schematic 11. BOP Schematic. If you required additional information, please contact me at A/C 432 - 620 - 4325. Sincerely, di Maria L. Perez, Regulatory Analyst Copy to: Paul Figel, Engineering Manager A/C 432 - 620 -6743 200 N. LORAINE, SUITE 800, MIDLAND, TEXAS 79701 r III , RECEIVED STATE OF ALASKA t- JUL 1 8 2012 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGCC 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 igi . Pull Tubing • - Time Extension ❑ Operations Shutdown ❑ Re -enter Susp. Well ❑ Stimulate ❑ Alter Casing ❑ Other: ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: XTO Energy Inc. Development 0 - Exploratory ❑ 178 -024 3. Address: Stratigraphic ❑ Service ❑ 6. API Number: 200 N. Loraine, Suite 800, Midland, Texas 79701 50- 733 - 20315 -00 -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 #C42 -23 - 9. Property Designation (Lease Number): 10. Field / Pool(s): ADL 18756 ' MGS E, F, G Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 9,850 9,306 9753 9161 NA NA Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 2578' 13.375" 2578' 2492' 2730 psi 1130 psi Intermediate 8822' 7.625" 8822' 8346' 4790 psi 6890 psi Production Liner 1224' 5.5" 9848' 9304' 7740 psi 6280 psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 9196 -9667 8697 -9134 3 1/2" & 2 7/8" L -80 9334 Packers and SSSV Type: Baker TE5 SSSV, Baker SABL -3 & Model M Pk Packers and SSSV MD (ft) and TVD (ft): SSSV © 297' MD & TVD, Pkr 1 (9132' & 8637' TVD), Pkr 2 (9312' & 8804' TVD) 12. Attachments: Description Summary of Proposal Ei 13. Well Class after proposed work: Detailed Operations Program ill BOP Sketch is Exploratory ❑ Development El ' Service ❑ 14. Estimated Date for 10/1/2012 15. Well Status after proposed work: Commencing Operations: Oil IN • Gas ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Paul Figel, Engr 432 - 620 -6743 Printed Name Maria Perez Title Regulatory Analyst Signature Phone 432 - 620 -4325 Date 7/17/2012 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 31 2 - 2 0 Plug Integrity ❑ BOP Test Mechanical Integrity Test ❑ Location Clearance ❑ Other: .t3OP - -7- t •7LQ ,57) ov p s i... Subsequent Form Required: ) t — 40 4- APPROVED BY �/ 2,? / Approved by C OMMISSIONER THE COMMISSION Date: ii�03 2 V/� J✓. z Z • (L �1 OR IGINAL Tti) k S ubmit in Duplicate i • T3 ENERGY July 17, 2012 To: John Norman Victoria Ferguson Cc: Scott Griffith Scott Landon From: Paul Figel Subject: Workover for MGS C42 -23 (178 -024): Replace failed 3 -1/2" Gas Lift string & reperf HK- _ HZ due to Barium Sulfate Scale. Objective: The objective for the workover proposed for the C42 -23, located on Platform C, Cook Inlet is to replace the current 3 -1/2" Gas Lift string that has 2 straddle packers across the HK -HN zones. Based upon the results from the Schlumberger Production Log that was performed in May 2012, the straddle packer completion has 2 leaks: 1) the "K" anchor on the top packer; 2) the bottom packer is leaking allowing in -flow from the isolated HK -HN zones. According to the production log, the "isolated" HK -HN is now contributing 72% of the total inflow (38 BO of the 53 BOPD) which most likely failed after the coil tubing acid treatment in 2010. Therefore, a new 2 -7/8" completion with 1 packer will encompass all the zones and will contend with the extra ±400 bbl water that was previously isolated. Barium sulfate scale was identified during the troubleshooting of these problems and could be restricting the HN -HR perfs. This zone has been on a 25% decline rate between the last 2 workovers in 2005 & 2010 and, therefore, will be reperforated to overcome the skin damage. Well History: The C42 -23 was completed in the East Flank Hemlock in 1978 @ 302 BOPD, 37 BWPD & 292 mscf /d. In 1978, the HK -HN was re -perf d increasing production from 400 BO & 200 BW to 714 BO & 30 BW. In 1985, a small 1500 gal xylene /HCL acid job was performed resulting in a 60 BO & 51 BW increase. In 1986, the GR -GS zone was tested with 2 shots and a 50 BO decrease occurred with cross -flow being suspect without a production log to verify. The GR -GS zone was never pursued for further development. A small 2000 gal Mud Acid job performed in 1987 did not impact production possibly due to the lack of xylene omitted from the stimulation fluid. In the following week, the production increased by 50 BO by adding 64' of HR -HZ perf's. In 1991, with wireline encountering scale and paraffin, a more extensive acid/xylene coil tubing treatment was performed. The production increased from 20 BO & 92 BW to 110 BO & 300 BW. Scale in both the tubing and across the perforations was a continuous problem from 1999 to 2003. Production was down to 12 BO & 12 BW. A coil tubing acid treatment was performed in 2003 using 10,000 gal of acid/xylene to spot, wash and squeeze the perfs. The production increased to 83 BO & 953 BW but was not sustainable due to the spacing of the 7 GLM's. Gas lifting was limited to valve #3 for steady operations. The well was logged with a basic spinner and temperature survey tool in 2004. The results showed the majority of the inflow was coming from the lower HK -HN • 2 - interval with little production from the HN -HR perfs. Therefore, in 2005, the completion was pulled. The GR -GS perforations were squeezed off and the HN -HR zones were acid -slick water frac'd with 71 bbl 10% HCL with 10% xylene & 475 bbl 20# linear gel @ 8 BPM @ 6,000 psi. A tapered gas lift string was run using straddle packers with a sliding sleeve over the HK -HN to initially produce the HN -HZ to reduce water and cross -flow effects. The production results were 30 BO & 472 BW prior and 88 BO & 314 BW after installation. As seen in the attached production plots, the total production increased by 700 BPD following a coil tubing stimulation in 2010. It was after this point that the integrity of the straddle packers were questioned as the production profile mimicked the 2003 treatment that was prior to the installation of the straddle packers in 2005. The high resolution production log that was run in May 2012 verified that the bottom packer was leaking allowing +300 BPD inflow from the HK -HN and that the "K" anchor on the top packer was also leaking permitting uncontrollable gas injection to bypass the orifice valve in mandrel #13. Barium sulfate scale was identified during the troubleshooting of these problems. 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, �? Paul Figel Engineering Manager WORKOVER SUMMARY for C42 -23 Scope of work: The main objective is to replace the failed straddle packers with a single packer that will be set on a new 2 -7/8" Gas Lift String that will allow all zones from the HK -HZ to produce. The HN -HR zones will be reperforated due to the presence of Barium Sulfate scale. Current Well Status: Producing 53 BO & 408 BW as of 7 -14 -12 on gas lift with 1340 mscf /d. Well Info: See Attached Procedure & TVD Survey. SSSV test — see attachment. MASP & Kill Weight: BHP = 4130 psi @ 9400' MD based on BHP survey done on 6 -9 -12. Kill weight: 4130 psi = (0.052) (8695' Top Perf TVD) (x, ppg) x = 9.4 ppg + 0.5 ppg = 9.6 ppg mud Mud Recipe will be 8.4 ppg FIW + 91 lbs/bbl KC1 MIT Info: NA as a producer BOP Ram Configuration: VPR for 2 -7/8" & 3 -1/2" 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. MA..s < 3000 psi. Contact Info: 2 RA-AA 57A . 0 i -p • Operations Engineer: Paul Figel, XTO Energy, 432 - 620 -6743, paul figel(dxtoenergy.com d°2 ?•iL • Superintendent: Scott Griffith, XTO Energy, 907 - 776 - 2506, scott_griffith ■,xtoenergv.com • • )( TO ENERGY MASP for C42 -23 (178 -024) Current Well Status: Producing 53 BOPD, 408 BWPD & 25 MCF/D on gas lift. Prod is 89% Water Cut. 8.4 ppg FIW = 0.437 psi/ft 34 API = 0.3702 psi /ft. Mid Perf TVD: 9431' Top Perf TVD: 8697' BHP = 4130 psi. Based upon a BHP survey performed on 6 -9 -12 @ mid perf. Phyd = (0.11)(0.3702 psi /ft)(8697') + (0.89)(0.437 psi/f1)(8697') = 3737 psi SP = 4130 — 3737 = 393 psi Paul Figel Engineering Manager 8 -10 -12 . - . , Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: XTO Energy Submitted By: Barney Phillips Date: 5/20/2012 Operator Rep: Barney Phillips Field/Unit/Pad: MGS XTO C Platform AOGCC Rep: Matt Herrera Separator psi: LPS 68/68 HPS 4 . 1. .ae'' . . ,., . , .. . , .. .4 4 . ..- . 4, .- . . , . _ . „.. , . . . , -4-_,, •. . — 4 , — — , ,.. . ,. .,:. , '.'' . , - ' 't . Well Permit Separ Set LIP Test Test Test Date Passed Retest Oil, WAG, GINJ, Inner Outer Tubing Yes/No Yes/No Number Number PSI PSI Trip Code Code Code Or Date Shut In GAS, CYCLE, SI PSI PSI PSI C12-23 1900200 68 37 38 P P P OIL 100 Yes No C13-13LN 2022130 1/1/2006 SI No No C13-23 1880990 68 37 38 P P P OIL 95 Yes No Cl3A-23 1901060 P P OIL 90 Yes No • C21-23 1890870 P P OIL 95 Yes No C21-26 1890040 P P OIL 100 Yes No C21A-23 1910440 P P OIL 95 Yes No C22-23 1880160 12/19/2004 SI Yes No C22-26RD 1760650 5/5/2012 SI Yes No C22A-26LIN 2041824 P P OIL 85 Yes No C24-26RD 1790620 4/1/1992 SI Yes No C31-26RD 2041400 P P OIL 90 Yes No C32-23LW 2020340 P P OIL 75 Yes No C34-26 1680190 11/1/1988 SI Yes No C42-23 1780240 P P OIL 95 Yes No C43-14 1881320 P P OIL 3425 No No Wells: 11 Components: 24 Failure 0 Failure Rate: 0.00% 0 ge 011W 411 Remarks: 1 PLB 01/26/11 Page 1 of 1 SVS MGS C Platform 5-20-12.xls MGS (E) C42 -23 10000 MIDDLE GROUND SHOAL EFG ] ,_ [ZS (q C42 -23 5000 1 CD Oil I- _ - CD V■kr �.._ CD Gas AS , 1 4. Test BOFD Alaska O Test BVFD Alaska 1000 I t. ' • A Test MCFFD Alaska _ n 500 \ t k ii ) - 11F1100 , , i '' 1 100 INIl1IIp1IvA 50 ' 1 r � k .1 IN itiii1:1111,1t ,11 f a 1 1 I . 11 10 5 1 1 1 -r- , , 1 , 2 77 79 80 81 82 83 84 85 86 87 88 89 90 91 92 93 94 95 96 97 98 9g00m102 03 04 05 06 07 08 09 10 1112 Cum Oil 1492934.181 Date 1 MGS (E) C42 -23 10000 _ -: , — MIDDLE GROUND SHOAL EFG - R./GS (E) C42 -23 5000 _ ca al - CDwr - CD Gas ♦ Test_BOFD Alaska 2005: WO to install o Test_BA4RJ Alaska Straddle pkrs 101111 1000 - & Test NCFFD Alaska • 0 r a ^. 500 - 2003: Coil tbg acid `' / ' 2010: Coil tbg acid ,i . 100 _ ' + 50 - ^� .. iik r 10 - \I\ ,,i-, 5 V , 1 4 1 2000 01 02 03 04 05 06 07 08 09 10 11 12 Cum Oil 1492934.181 Date • • 1 1 Wile WOWS 1 C Platform, Well C42 -23 L INTEQ Alaska State Plane Coordinates Measured Angle Azimuth TVD -RKB TVD X Y N / -S E / -W DLS Vert. Sec SVY# Depth deg deg ft Subsea ft ft ft ft deg /100 ft ft Tie -In 0.00 0.00 0.00 0.00 - 105.00 231413.99 1 2474195.36 0.00 0.00 0.00 0.00 1 10.00. 0.00 161.00 10.00 -95.00 2474195.36 0.00 0.00 0.00 0.00 2 360.00 1.25 161.001 359.97 254.97 231415.15 2474191.72 -3.61 1.24 0.36 -3.74 3 397.00 1.75 143.00 396.96 291.96 231415.60 2474190.88 -4.44 1.71 1.84 -4.63 4 427_00 3.00 120.00 426.93 321.93 231416.54 2474190.10 -5.20 2.67 5.16 -5.51 5 458.00 3.00 106.00 457.89 352.89 231418.00 2474189.44 -5.83 4.15 2.36 -6.34 6 492.00 2.00 80.00 491.86 836.86 231419.44 2474189.26 -5.97 5.59 4.38 -6.67 7 518.00 1.00 83.00 517.85 412.85 231420.11 2474189.35 -5.87 6.26 3.86 -6.66 8 548.00 2.00 70.00 547.84 442.84 231420.87, 2474189.55 -5.66 7.021 3.50 -6.55 9 578.00 2.75 45.00 577.82 472.82 231421.89 2474190.21 -4.97 8.02 4.21 -6.00 10 608.00 3.50 35.00 607.77 502.77 231422.95 2474191.45 -3.71 9.05 3.08 -4.89 11 639.00 4.00 41.00 638.70 533.70 231424.24 2474193.01 -2.12 10.30 2.05 -3.49 12 671.00 5.00 63.00 670.61 565.61 i 231426.25 2474194.44 -0.64 12.28 6.18 -2.29 13 731.00 5.75 68.00 730.34 625.34 231431.41 2474196.64 1.67 17.39 1.47 -0.69 14 823.00 6.50 57.00 821.82 716.82 231440.16 2474201.00 6.23 26.04 1.51 2.67 15 886.00 5.25 65.00 884.49 779.49 231445.83 2474204.03 9.39 31.64 2.37 5.05 16 1015.00 4.50 65.00 1013.02 908.02 231455.87 2474208.44 14.03 41.57 0.58 8.30 17 1075.001 3.75 66.00 1072.87 967.87 231459.83 2474210.14 15.82 45.50 1.26 9.55 18 1145.00 4.50 55.00 1142.69 1037.69 231464.23 2474212.55 18.33 49.84 1.55 11.44 19 1210.00 5.25 21.00 1207.46 1102.46 231467.48 2474216.71 22.57 53.00 4.52 15.22 20 1273.00 7.50: 354.00 1270.08 1165.08 231468.24 247422348 29.35 53.60 5.86 21.86 21_ 1333.00 9.50 345.00 1329.42 1224.42 231466.74 2474232.20 38.03 51.91 3.99 30.69 22 1418.00 13.00 341.00 1412.781 1307.78 231462.18 2474248.12 53.85 46.98 4.22 47.03 23 1545.001 18.75 346.00 1534.89 1429.89 231453.34 2474281.67 87.19 37.38 4.65 81.36 24 1638.00 21.00 346.001 1622.34 1517.34 231446.39 2474312.51 117.86 29.73 2.42 112.78 25 1720.00 21.50 349.00 1698.77 1593.77 231440.63 2474341.66 146.87 23.31 1.46 142.39 26 1877.00 21.75 349.00 1844.72 1739.72 231430.89 2474398.69 203.67 12.27 0.16 200.16 27 2177.00 22.25 349.00 2122.881 2017.88 231411.96 2474509.47 313.99 -9.17 0.17 312.36 28 2342.00 22.25 346.00 2275.59 2170.59, 231399.83 2474570.73 374.96 -22.69 0.69 374.60 29 I 2405.00 22.50 348.00 2333.85 2228.85 231394.97 2474594.22 398.33 -28.08, 1.27 398.48 30 2545.00 23.00 348.00 2462.96 2357.96 231384.92 2474647.411 451.28 -39.34 0.36 452.47 31 2664.00 23.00 348.00 2572.50 2467.50 231376.29 2474693.10 496.76 - 49.01 0.00 498.84 32 2852.00 23.00 348.00 2745.55 2640.55 231362.66 2474765.28 568.62 -64.28 0.00 572.09 33 3041.00 24.25 348.00 2918.71 2813.71 231348.60 2474839.70 642.70 -80.03 0.66 647.62 34 3228.00 24.75 347.00 3088.87 2983.87 231333.54 2474915.77 718.41 -96.82 0.35 724.90 35 3417.00 24.00 347.00 3261.03 3156.03 231317.73 2474992.15 794.41 - 114.36 0.40 802.57 36 3666.00 23.75 346.00 3488.72 3383.72 231296.44 2475090.65 892.40 - 137.88 0.19 902.84 37 3881.00 24.00 344.00 3685.33 3580.33 231275.83 2475175.18 976.44 -160.41 0.39 989.15 38 4063.00 25.75 343.00 3850.44 3745.44 231255.74 2475249.05 1049.84 - 182.17 0.99 1064.81 39 4210.00 25.50 349.00 3983.00 3878.00 2475310.99 1111.44 - 197.55 1.77 1 1127.93 40 4336.00 23.75 350.00 4097.54 3992.54 231233.37 2475362.81 1163.06 - 207.13 1.43 1180.36 41 4422.00 22.00 349.00 4176.77 4071.77 , 231228.04 2475395.81 1195.93 - 213.21 2.08 1213.75 42 4528.00 20.75 348.00 4275.48 4170.48 231221.21 2475433.83 1233.79 - 220.91 1.23 1252.30 43 4684.00 19.00 348.00 4422.18 4317.18 231211.36 2475485.94 1285.66 - 231.93 1.12 1305.19 44 4860.00 18.75 348.00 4588.72 4483.72 231200.80 2475541.89 1341.35 - 243.77 0.14 1361.97 45 5031.00 18.501 348.00 4750.76 4645.76 231190.66 2475595.55 1394.77 - 255.12 0.15 1416.43 46 5249.00 17.50 349.00 4958.09 4853.09 231178.72 2475661.84 1460.78 - 268.57 0.48 1483.65 47 5470.00 17.75 348.00 5168.71 5063.71 231166.87 2475727.70 1526.35 - 281.91 0.18 1550.42 48 5603.00 17.75 347.00 5295.38 5190.38 231159.00 2475767.47 1565.93 - 290.69, 0.23 1590.82 49 5829.00 16.75 345.00 5511.22 5406.22 231144.30 2475832.85 1630.96 - 306.87 0.51 1657.44 50 5872.00 , 17.25 348.00 5552.34 5447.341231141.65 2475845.13 1643.18 - 309.80 2.35 1669.94 1 e [ • • Measured Angle Azimuth TVD -RKB TVD X Y N / -S E / -W DLS Vert. Sec SVY# Depth deg deg ft Subsea ft ft ft ft deg /100 ft ft 51 5949.00 17.25 354.00 5625.88 5520.88 231138.60 2475867.73 1665.71 - 313.37 2.31 1692.74 52 6037.00 18.50 3.00 5709.65 5604.65 231138.58 2475894.66 1692.63 - 314.00 3.44 1719.50 53 6131.00 19.50 4.00 5798.53 5693.53 231141.15 2475925.16 1723.17 -312.12 1.12 1749.52 54 6232.00 20.25 4.00 5893.51 5788.51 231144.32 2475959.34 1757.43 - 309.73 0.74 1783.13 55 6422.00 20.50 4.001 6071.62 5966.62 231150.43 2476025.21 1823.42 - 305.11 0.13 1847.90 56 6671.00 19.50 358.00 6305.63 6200.63 231153.96 2476110.19 1908.46 - 303.52 0.92 1931.95 57 6828.00 19.25 357.00 6453.74 6348.74 231152.87 2476162.26 1960.49 - 305.79 0.26 1983.82 58 6989.00 18.75 355.00' 6605.97 6500.97 231150.42 2476214.61 2012.77 - 309.44 0.51 2036.11 59 7174.00 18.50 354.00 6781.28 6676.28 231146.10 2476273.53 2071.58 - 315.10 0.22 2095.15 60 7243.00 18.50 353.00 6846.71 6741.71 231144.12 2476295.34, 2093.34 - 317.57 0.46 2117.04 61 7425.00 18.25 353.00 7019.43 6914.43 231138.42 2476352.43 2150.28 - 324.57 0.14 2174.40 62 7645.00 18.25 352.00' 7228.37 7123.37 231130.99 2476420.92 2218.58 - 333.56 0.14 2243.30 63 _ 7784.00 18.25 351.00 7360.37 7255.37 231125.53 2476464.10 2261.63 - 339.99 0.23 2286.82 64 7979.00 19.75 3.00 7544.82 7439.82 231123.92 2476527.24 2324.72 - 343.05 2.14 2349.74 65 8121.00 19.25 3.00 7678.67 7573.67 231127.47 2476574.50 2372.06 - 340.57' 0.35 2396.31 66 8321.00 18.50 359.00 7867.92 7762.92 , 231130.11 2476639.11 2436.71 - 339.39 0.75 2460.22 67 8485.00 17.75 0.00 8023.79 7918.79 231130.82 2476690.12 2487.72 - 339.85 0.50 2510.83 68 8582.00 17.75 359.00 8116.17 8011.17 231131.24 2476719.69 2517.29 - 340.11 0.31 2540.17 69 8802.00 17.57 0.00 8325.80 8220.80 231132.17 2476786.42 2584.03 - 340.69 0.16 2606.37 70 8948.00 17.50 356.00 8465.02 8360.02 . 231131.64 2476830.38 2627.97 - 342.22 0.83 2650.11 71 9089.00 22.50 352.00 8597.48 8492.48 231127.49 2476878.38 2675.86 - 347.46 3.67 2698.28 72 9236.00 23.00 351.00 8733.05 8628.05 231120.36 2476934.78 2732.08 -355.87 0.43 2755.12 73 9600.00' 21.00 348.00 9070.53 8965.53 231098.73 2477069.36 2866.14 - 380.56 0.63 2891.28 74 9706.00 21.00 346.00 9169.50 9064.50 231091.03 2477106.55 2903.14 - 389.10 0.68 2929.10 75 ! 9820.00 18.00 345.00 9276.94 9171.94 231082.37' 2477143.60 2939.99 - 398.60 2.65 2966.89 76 9850.00 18.00 345.00 9305.48 9200.48 231080.18 2477152.60, 2948.94 - 401.00 0.00 2976.08 2 • . /To ERGY XTO Energy Inc. MGS C42 -23 EAST FLANK, COOK INLET, ALASKA Recompletion Procedure WELL DATA: SURFACE CASING: 13 -3/8" 54.5, 61# K55. Set @ 2,578'.Cmt w/ 2,100 sx. INTERMEDIATE CASING: 7 -5/8" 29.7, 33.7 #, N80. Set @ 8,822'.Cmt w/ 450 sx. PRODUCTION LINER: 5 -' /2" 17 #, N80, @ 8,624 — 9,848'. Cmt w/ 210 sx.Sqz liner top w/ 150 sx. TUBING: 3 '/2" 9.3 #, L808rd Surface to 8525' 2 -7/8" 6.5# , L80 8rd 8525 — 9364' PACKERS: 5 -1/2" Baker SABL -3 Penn Pkr @ 9162' 5 -1/2" Baker Model F Penn Pkr @ 9342' PERFORATIONS: GR -GS: 8,675 &8,679' CmtSgz'd4 -25 -05 HK -HN: 9,196 — 9,215' Isolated behind tandem Pkrs HK -HN: 9,260 — 9,332' Isolated behind tandem Pkrs HN -HR: 9,367 — 9,503' HR -HZ: 9,527 — 9,603' HR -HZ: 9,604 — 9,667' NET PAY: 275' MAX HOLE DEVIATION: 25 Degrees BHST: 160 Deg F BHP: 4130 psi(Based on BHP survey 6- 9 -12.) SMALLEST ID: XN Nipple: 2.205" ID @ 9327' CURRENT PROD: Prod @ 53 BOPD &408 BWPDas of 7- 14 -12. (Inj gas @ 1340 MSCF.) OBJECTIVE: Pull failed Straddle Packers, Reperf HK -HZ & replace 3 -1/2" GL String w/ 2 -7/8" tbg. NOTE: • AFE #1200562 • SD gas liftl week prior to MIRU. • SL to pull OV @ GLM #13 prior to MIRU derrick • 9.6ppg Salt mud to kill well. • The HK -HZ will be reperf'd due to Barium Sulfate scale issues. 8 -8 -12 C: \temp \Temporary Internet Files \OLK86 \C42 -23 Recompletion Procedure 8- 8- 12.docx • • 2 Materials Rqd: • 200 bbl Gel Pill (2 #/bbl FloZan + 3 gal Greencide) (Provided by MI) • 46,000 lbsKC1 (500bbls9.6ppg mud) 91 lbs KCL/bbl FIW (Save mud for C24 -23, C24 -26RD & C34 -26) PROCEDURE: 1. RU Slickline & lubricator. Press test lubricator to 1000 psi. RIH w/ pulling tool to GLM #13 @ 9143'. Latch & POOH the OV. RD lubricator. 2. MIRU Derrick. Circ well with 9.6 ppg mud. (Hole vole = 380 bbl)@ 4 BPM to the prod header through GLM @ #13. Check to make sure well is dead. Recover & maintain mud weight. 3. MI 9800' 2 -7/8" 10.4# SLH90 HT drill pipe (1.975" ID) & 9 ea 3 -1/8" DC (1.5" ID). 4. Notify the AOGCC 48 hrs prior to the BOP test. Set BPV's and ND the WH. Install riser & NU BOP's. Pull BPV's & set double check valves. Ensure BOP has VPR pipe rams for 2 -7/8" & 3 -1/2" tbg. Press test BOP's to 250 psi & 5000 psi. Send WH to Cameron for inspection. 5. RU Pollard WL. RIH w/ Jet Cutter w/ CCL on WL & cut in the middle of the 6' pup it (al ±9125' that is above the K- Anchor on the top pkr. RD WL.Keep WL on board for perf ing on Step #9. 6. RU slips and tongs for 3 -1/2" tbg. POOH & LD ±8500' 3 -1/2" tbg. Change out slips and tongs to 2- 7/8". Continue POOH & LD 620' of 2 -7/8" tbg. Check for NORM. Send tbg to onshore to be sold for scrap. Send in tbg hanger to Cameron. New hanger to be 2 -7/8 ". 7. RIH w/ OS to 2 -7/8" TOF @ ±9128'. Rotate out K anchor & POOH. MU 5 -1/2" Packer milling BHA on 3 -1/8" DC's & 2 -7/8" DP. RIH to top of pkr (cry, 9132', Establish string weight. Mill packer per packer milling procedures. Circ bottoms up w/ 20 bbl gel sweep. POOH with the packer &180' 2 -7/8" tbg & lower pkr seals. If packer does not come out, RIH with spear & grapple to retrieve the packer. 8. RIH w/ 5 -1/2" Packer milling BHA to 2 packer A9312'. Establish string weight. Mill packer per packer milling procedures. Circ bottoms up w/ 20 bbl gel sweep. POOH w4 pkr & 22' tailpipe. LD Milling BHA. If packer did not come out,RIH with spear & grapple to retrieve pkr. 9. RIH w/ 4 -5/8" bit, 19 jts DP ( ±570'),casing scraper for 5 -1/2" 17# on DP. Scraper to be spaced out to stay above perfs. TU @ PBTD 9753' &rev circ 20 bbl gel sweep. POOH & LD DP. 10. RU Pollard WL. Correlate to the Dresser Atlas GR/CCL/Neutron Log dated 6 -2 -78 &perf the HN- efiev( HR: 9367 - 9503', HR -HZ: 9527 -9603' & 9604 -9667' A 2 spf (a 120 deg phasing on 3 -3/8" guns. (275 Net ft w/ 550 total holes.) 11. MI 9400' 2 -7/8" 6.5# L80 8rd EUE tbg (incl 4% excess). 12. RIH w/ TIW 5 -1/2" HB -BP L80 Permanent Packer on 2 -7/8" 6.5# L80 8rd EUE tbg and land as follows: 8 -8 -12 C: \temp \Temporary Internet Files \OLK86 \C42 -23 Recompletion Procedure 8- 8- 12.docx • • 3 Item Length, ft Top Bottom 2 -7/8" 6.5# L80 8rd EUE 300 0 300 4' 2 -7/8" 6.5# L80 8rd EUE Pup Jt 4 300 304 2 -7/8" Baker TE5 SSSV (2.313" ID) 1 304 305 4' 2 -7/8" 6.5# L80 8rd EUE Pup Jt 4 305 309 2 -7/8" 6.5# L80 8rd EUE 8,779 309 9,088 4' 2 -7/8" 6.5# L80 8rd EUE Pup Jt 4 9,088 9,092 2 -7/8" X Nipple (2.313" ID) 8rd 9Cr 1 9,092 9,093 6' 2 -7/8" 6.5# L80 8rd EUE Pup Jt 6 9,093 9,099 Anchor w/ Seals 1 9,099 9,100 5 -1/2" TIW HB -BP Permanent Packer L80 4 9,100 9,104 10' Millout Extension L80 10 9,104 9,114 X O' er MOE to 2 -7/8" 8rd L80 1 9,114 9,115 6' 2 -7/8" 6.5# L80 8rd EUE Pup Jt 6 9,115 9,121 2 -7/8" XN Nipple (2.205" ID) 8rd 9Cr (RHCP Installed) 1 9,121 9,122 4' 2 -7/8" 6.5# L80 8rd EUE Pup Jt 4 9,122 9,126 W L REG L80 1 9,126 9,127 GLM MD TVD PORT PSC PSO #1 2099 2050 12 942 1000 #2 3569 3400 12 922 962 #3 4555 4300 12 902 936 #4 5346 5050 12 883 905 #5 5870 5550 12 864 886 #6 6400 6050 14 834 863 #7 6931 6550 14 814 843 #8 7458 7050 14 792 821 #9 7985 7550 14 769 798 #10 8513 8050 14 744 772 #11 9039 8550 14 Orifice Each GLM will have a 4' pup jt on top & 6' pup jt on bottom. 13. RU Slickline & press test lubricator to 4,000 psi. RIH w/ "N" test tool plug and seat on XN nipple @ 9121'. Press test tbg to 1,000 psi for 15 min. Monitor falloff. Con't to press up to +3,500 psi to set packer. Hold a 4,000 psi press test on the tbg for 15 min. Bleed off the tbg press. RU pump on the tbg by casing annulus. Estcirc down the tbg annulus through the tbg at a maximum pump rate of 2 BPM. Close the TIW valve on the tbg. Perform a MIT on the casing to 2000 psi. Monitor for 30 min. Bleed -off press. `1 . -1 Q` IA 14. POOH w/ test tool. RD Slickline. 15. Set BPV. ND BOP's & riser. NU new 2 -7/8" L80 WH & pull BPV. Set 2 way check& test WH to 5,000 psi. Pull out 2 way check. Release Rig. PWO GL. Paul Figel Engineering Manager 8 -8 -12 C: \temp \Temporary Internet Files \OLK86 \C42 -23 Recompletion Procedure 8- 8- 12.docx • • - PLF 5 -25 -12 - )(TO ENERGY Current Completion KB: 35 r# Water Depth: 73' MSL MGS C42 -23 Cook Inlet, Alaska Tbg: 3 -Y" 9.3# L80 8rd EUE surf - 8,495' Leg 4, Conductor 25 2 -7/8" 6.5# L80 8rd EUE 8,495 - 9,334'. r Set: 5 -4 -2005 API No.: 50- 133 -20315 Spud: 3 -13 -78 3 - %2' Baker TE5 SSSV (2.81" ID) @ 297' X -over 3-W 9.3# 8rd to 2 -7/8" 6.5# L80 8rd @ 8,495' Alre 4. 2 -7/8" X Nipple (2.313" ID) 9Cr @ 9,124' 6' Pup Jt, 2 -7/8" 6.5# L80 8rd EUE @ 9,125' Surf Csg: 13 3/8 ", 54.5/61 Ib, K55. 'Baker K Anchor @ 9,131' Baker 5 -'W SABL -3 Perm Packer @ 9,132' Set @ 2,578'. Cmt w/ 2,100 sx. 6' Millout Extension @ 9,136' X -over MOE Box X 2 -7/8" 6.5# 8rd Pin @ 9,142' 4' Pup Jt, 2 -7/8" 6.5# L80 8rd EUE @ 9,142' 2 Jts tbg 2 -7/8" 6.5# L80 8rd EUE @ 9,146' 6' Pup Jt, 2 -7/8" 6.5# L80 8rd EUE @ 9,209' 2 -7/8" GLM w/ Equalizing Valve @ 9,216' Intermediate Csg: 7 5/8" 29.7/33.7 lb, 4' Pup Jt, 2 -7/8" 6.5# L80 8rd EUE @ 9,223' N80. Set 8,822'. 5/8" 29.7/33.7 7 l 6' Pup Jt, 2 -7/8" 6.5# L80 8rd EUE @ 9,226' @ Baker 2 -7/8" CMU S Sleeve (2.313" ID) @ 9,232' TOC @ ±6,642'. 4' Pup Jt, 2 -7/8" 6.5# L80 8rd EUE @ 9,236' A or pi 01 2 Jts tbg 2 -7/8" 6.5# L80 8rd EUE @ 9,240' 8' Pup Jt, 2 -7/8" 6.5# L80 8rd EUE @ 9,303' p 0 04 ,A re. , (Boao w/ @ ,' 9,312' Baker aker 54 2c" t Mode17F' r Bonded Perm Packer Seals (45 -30) 9 311 @ aker 5' SBE @ 9,314' X -Over Acme Box X 2 -7/8" 6.5# 8rd Pin @ 9,318' 8' Pup Jt, 2 -7/8" 6.5# L80 8rd EUE @ 9,319' Fre 0001# 2 -7/8" XN Nipple (2.205" ID) 9Cr @ 9,327' Op , 4' Pup Jt, 2 -7/8" 6.5# L80 8rd EUE @ 9,329' f WLREG @ 9,334' ira r { ,• GR -GS: 8,654' & 8,689' (2 holes) PO „Asts; w4 SQZ'd w/ 70 sk on 4- 25 -05. krii Prod Liner: 5 -1/2 ", 17 Ib, N80. S '46L- ° 3 �r3z Set @ 9,848'. TOL @ 8,624'. " " I ' Cmt w/ 210 sx. Sqz TOL w/ 150 sx. HK -HN: 9,196' 9,215 I'll GLM MD TVD PORT PSC PSO � i HK -HN: 9,260'- 9,332' #1 1888 1855 10 920 955 _ #2 3139 3008 12 910 954 " O' a1 31-1 iTs g t� #3 4236 4007 12 900 934 #4 5088 4805 16 890 931 r 11 #5 5601 5293 16 880 915 0 010, HN -HR: 9,367'- 9,503' #6 6078 5749 16 870 905 / #7 6562 6204 16 860 893 �/y #8 7039 6653 16 850 883 0 4 HR -HZ: 9,527'- 9,603' #9 7519 7108 16 840 872 re, #10 7972 7538 16 830 855 #11 8356 7901 12 ORIFICE ■ - HR -HZ: 9,604'- 9,667' #12 8783 8308 20 810 838 0 0 0 ri #13 9143 8648 20 ORIFICE / Fish: GLV on btm (3- 24 -07) 4 110 0 ,04 FILL: None (10- 30 -10) PBTD: 9,753' MD (9,161' TVD) TD: 9,850' MD (9,306' TVD) • • �O PLF 7 -16 -12 F . N E R G Y PROPOSED COMPLETION KB: 35' w r Water Depth: 73' MSL MGS C42 -23 • Cook Inlet, Alaska 0 TBG: 2 -7/8" 6.5# L80 8rd EUE Surf to 9127' Leg 4, Conductor 25 or Set API No.: 50- 133 -20315 Spud: 3 -13 -78 4' Pup Jt 2 -7/8" 6.5# L80 8rd EUE @ 300' CI et 2 -7/8" Baker TE5 SSSV (2.313" ID) @ 304' 4' Pup Jt 2 -7/8" 6.5# L80 8rd EUE @ 305' ±283 Jts 2- 7/8 "6.5# L80 8rd EUE Surf Csg: 13 3/8 ", 54.5/61 Ib, K55. 4' Pup Jt 2 -7/8" 6.5# L80 8rd EUE @ 9088' Set @ 2,578'. Cmt w/ 2,100 sx. 2 -7/8" X Nipple (2.313" ID) 8rd 9Cr @ 9092' 6' Pup Jt 2 -7/8" 6.5# L80 8rd EUE @ 9093' TIW Anchor w/ Seals @ 9099' 5 -Y" TIW HB -BP Perm Pkr L80 @ 9100' 10' MOE L80 @ 9104' v,,. re X -over MOE to 2 -7/8" L80 8rd @ 9114' Intermediate Csg: 7 5/8" 29.7/33.7 Ib, V 6' Pup Jt 2 -7/8" 6.5# L80 8rd EUE @ 9115' N80. Set @ 8,822'. Cmt w/ 450 sx. 2 -7/8" XN Nipple (2.205" ID) 8rd 9Cr @ 9121' TOC @ ±6,642'. 11 11 4' Pup Jt 2 -7/8" 6.5# L80 8rd EUE @ 9122' dar i WLREG @ 9126' A Air pr ro, 0 000 014 P r fr o, rerAi GR -GS: 8,654' & 8,689' (2 holes 00 • ,rror. ' ' ( holes) W e) SQZ'd w/ 70 sk on 4- 25 -05. 4 �1 — e.. • Prod Liner: 5 -1/2 ", 17 lb, N80. S 0 et @ 9,848'. TOL @ 8,624'. OA HK-HN: 9,196'- 9,215' Cmt w/ 210 sx. Sqz TOL w/ 150 sx. Ae ______, GLM MD TVD PORT PSC PSO HK -HN: 9,260'- 9,332' #1 2099 2050 12 942 1000 0 #2 3569 3400 12 922 962 °r #3 4555 4300 12 902 936 01 A #4 5346 5050 12 883 905 HN -HR: 9,367'- 9,503' ( 11- e -44 #5 5870 5550 12 864 886 #6 6400 6050 14 834 863 /� #7 6931 6550 14 814 843 HR -HZ: 9,527'- 9,603' �64"' #8 7458 7050 14 792 821 #9 7985 7550 14 769 798 1 t' reid #10 8513 8050 14 744 772 HR -HZ: 9,604' - 9,667' a.' #11 9039 8550 14 Orifice P ', A 0, P FILL: None (10- 30 -10) PBTD: 9,753' MD (9,161' TVD) TD: 9,850' MD (9,306' TVD) .. • • . . .. re CAMERON XTO PLATFORM C Well 42 -23 EQUIPMENT Tree 3 -1/8 API 5K Run with 2 -1/16 API 5K Wing Valves in run of tree use R -35 Ring Gaskets Valve on wing use R -24 Ring Gaskets Tubing Hanger has 3" Type H BPV Profile go on MI / \ o© \ ' � L of OO i® Pneuma is il R -35 ° ° 1 Nu NMI sal Mt - WI R-35 ,T, . r / 1 i N SSV 1 ir. I -1..---m o L0 0 6 , ,, 8 , 5 „ © 1. " ... ■ Tubing Head Adapter is 1111111^ A 7- 1/16" API 5K x 3 -1/8 API 5K 6" R-46 Ring Gasket Bottom _ : I-- R -35 Ring Gasket Top E=li R-46 j � use ! I IMO 6' Tubing Spool _ I ,- , • • 13 -5/8 API 3K x 7 -1/16 " API 5K �,o o t o � ` o - R -57 Ring Gasket Bottom -rr, u1::tO I ■IlV i Pneumatic R 46 Ring Gasket Top _)� ° ` /r ° ` SSV 2 I Annulus Outlets are 2 -1/16 API 5K R -24 "II �� 2 -1116 API 5' R -24 Ring Gasket 5k'5k'""'" ' 3 7" 1' ' - � �mii' R -24 Ring Gasket R -57 a- mg Lowermost Casing Head ii! 1 _ 13 -3/8 SOW x 13 -5/8 API 3K Top ` jul R -24 " III ���I a'{ NO AN�E Annulus Outlets are 2 -1/16 API 3K -) ` 1 5 R -24 Ring Gasket ie *NO ANNULUS VALVE ON CASING HEAD R 24 API a l R -24 Ring Gasket I— ! • • 5/23/2012 13.625 BOP Schematic.xls XTO - ENERGY KB Elevation Date: 5/23/2012 "Rig Floor" I--1 Flow Flow line Nipple \o Hydril / 13 5/8" 5m \ 13 5/8" 5m Annular double ram preventer rrn �mm f171 r111 t) • X 77..,s v81- �' 13 5/8" Sm Cameron J II i �� Pipe rams Illi 21 \ 6 13 5 /8" 5m Cameron i dl Lii Blind Rams os......4_ • n m 11 n m U • 'Il 1 1 , 401 , Al It : 11 1 110110 - ' 2 1/16" Kill Line 3 1/8 "Choke Line 111 11 11 III 11 1. \ 21/16" 31/8 31/8 5 5m 5m Hydraulic Manual Manual Valve Valves / valve / 13 5/8 5m riser 135/8 "5m 1t>�wID�LU1 Mud Cross with 3 1/8" outlets Page 1 - vawf {{ I trslLOle STATE OF ALASKA ALASKJOL AND GAS CONSERVATION COMMIS REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon Ll Repair Well Lj Plug Perforations Stimulate ✓ Other Ln rL p W (tOV Performed: Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver ❑ Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Perforate ❑ Re -enter Suspended Well ❑ 2. Operator XTO Energy Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development ❑✓ Exploratory ❑ 178 -0240 3. Address: 200 N. Loraine, Suite 800, Midland, Tx 79701 Stratigraphic❑ Service ❑ 6. API Number: 50- 733- 20315 -00 -00 7. Property Designation (Lease Number): 8. Well Name and Nurnkeer: • ADL 18756 Middle Ground Shoal #C42 -23 9. Field /Pool(s): MGS E, F, G Oil Pool 10. Present Well Condition Summary: Total Depth measured 9,850 feet Plugs measured feet true vertical 9,306.00 feet Junk measured feet Effective Depth measured 9,753 feet Packer measured feet true vertical 9,161 feet true vertical feet Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 2,578' 13 -3/8" 2,578' 2,492' 2730 psi 1130 psi Intermediate 8,822' 7 -7/8" 8,822' 8,346' 4790 psi 6890 psi Production Liner 1,224' 5 -1/2" 8,624'- 9,848' 9304' 7740 psi 6280 psi Perforation depth Measured depth 9,196'- 9,667' feet ola N ov 10 True Vertical depth 8,693'- 9,134' feet Tubing (size, grade, measured and true vertical depth) 3- 1/2 ",9.3 #,L -80 Surf- 8,525' 2- 7/8 ",6.5 #,L80 8,525'- 9,364' Packers and SSSV (type, measured and true vertical depth) Baker ABL Pe rm 9,162' BakerF Perm 9,342' 11. Stimulation or cement squeeze summary: Intervals treated (measured): 9,365'- 9,700' f t T }- 5 2010 Treatment descriptions including volumes used and final pressure See attached daily report. A104 ki all & ft be= .Comd"Ift 12. Representative Daily Average Production or Injection i�t� Oil -Bbl Gas -Mcf I Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 98 18 1656 1810 psi 13. Attachments: 14. Well Class after work: Copies of Logs and Surveys Run Exploratory El Development 0� Service ❑ Stratigraphic ❑ Daily Report of Well Operations Attached 15. Well Status after work: Oil I ✓ Gas WDSPL GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 16. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 1 310-200 Contact Paul Figel, Engr. - Tel. No. 432 - 620 -6743 Printed Name Maria Perez T it l e Regulatory Analyst Signature '/ A Phone 432- 620 -4325 Date 10/18/2010 Form 10 -404 Revised 10/2010 Submit Original Only X E Review Well Chronolgy ERGY Well Name: Middle Ground Shoal C42 -23 API /UWl XTO Well ID Number District Area Field Name State County 5073320315 62275 South Permian Alaska Middle Ground Shoal Alaska I Kenai Peninsula Spud Date Orig KB Elev (ft) Ground Elevation (ft) KB- Ground Distance (ft) Location 3/30/1978 105.00 Job:7! InSttal Jgb>T e? #a -lZ tee , �. ...3 �� ... t ..,...., Job Category Primary Job Type / Initial Job Type Start Date End Date AFE Number AFE Type Total AFE Amount Total Field Estimated Cost AFE -Field Estimate Rig Rig Number Rig Start Date Rig Type :,: - lye R D a lly Start r Date Report End Date Daily Cost � �3 <, „ ..... : ` - p p Total Cum Cost To Date Operation Summary # 1 Scale'Removal, 5/5/2Q09, 20 .. i I. Coil:Tubm (1 i4citi2e8 /25/24 , , r� fi .x x2 :.... Job Category Primary Job Type / Initial Job Type Start Date End Date Well Maintenance Coil Tubing Clean & Acidize 8/25/2010 8/26/2010 AFE Number AFE Type Total AFE Amount Total Field Estimated Cost AFE -Field Estimate 100371 Remedial Workover 1 1 215,939.00 - 215,939.00 Rig Rig Number Rig Start Date Rig Type Dail Q` er'ations » �- Rpt No. Start Date Report End Date Daily Cost Total Cum Cost To Date Operation Summary # 1 1.0 8/25/2010 8/26/2010 1,670.00 1,670.00 MIRU Schlumberger 1.75" Coil tbg unit. Test BOP's @ 250 low psi & 5000 high psi (Chuck Scheve w/ state of Alaska waived witnessing the BOP test) - MU BHA 1.5 Scale Blaster/ 1.82 od gauge ring cmic Larry Driskill www.xtoenergy.com Page 1/2 Report Printed: 10118/2010 • Review Well Chronolgy Well Name: Middle Ground Shoal C42 -23 ENERGY API /UWI XTO Well ID Number District Area Field Name State County 5073320315 tU275 S outh Perm _ Alaska Middle Ground Shoal Ala Kenai Peninsula Spud Date brig KB Elev (ft) Ground Elevation (ft) KB- Ground Distance (ft) Location 3/30/1978 1 05.00 — - - - - -- - - -- - -- — Daily O erations Rpt No. Start Date Report End Date Daily Cost Total Cum Cost To Date Operation Summary # 1 2.0 8126/2010 8/27/2010 8,275.00 9,945.00 RIH w/ scale blaster@ 60 fpm, slowing to 5 fpm & making 2 passes across GLM's. Pumping slick 3% FIW 1.4 bpm - Jet wash production tbg f/ 9100 to 9364 @ 10 fpm & on to btm 9757' pbtd @ same rate. Cir hole clean w/ 20 bbl flo -vis followed w/ 80 bbl slick 3% FIW - Lay 8 bbl 10% acid f/ 9700 to 9367, displace w/ slick 3% FIW. PU CT to 9100, let soak f/ 30 min. RIH to 9700'@ 10 fpm while cir slick 3% FIW - Acid wash Peres 9667 to 9367 w/ 45 bbl 10% acid @ 1.5 bpm moving CT @ 20 fpm Making 1 pass up & 1 pass dn. RIH cir hole clean w/ 20 bbl flo -vis followed by 80 bbl slick 3% FIW @ 1.5 BPM - Shut in the CT annulus inject (all the acid) 234 bbl of 10% acid while making 6 passes across the interval f/ 9680 to 9365' @ 5 -10 fpm, .7 bpm, 3800 psi, 2600 whp - Displace acid w/ 180 bbl of 3% KCL FIW, mixed w/ 100 gal Nalco EC6079A Scale Inhibitor. Inject @ .7 bpm, 3500 psi, 2800 whp, while making 6 passes across interval f/ 9680 - 9365'@ 5 -10 fpm. Open CT annulus POH w/ CT cmic Larry Driskill Rpt No. Start Date Report End Date Daily Cost Total Cum Cost To Date Operation Summary # 1 3.0 8/27/2010 8/28/2010 205,994.00 215,939.00 Finish POH, Blow do CT w/ nitrogen. Break do BHA, Rig do injector, BOP's & riser - Tie int top o f tre & b flow tbg to PTS ta nk Rpt No. Start Date Report End Date Daily Cost Total Cum Cost To Date Operation Summary # 1 4.0 9/3/2010 9/4/2010 215,939.00 Put well into production h eader. - - -- - -- — — - - - -- i, Rpt No. Start Dale Report End Date Daily Cost Total Cum Cost To Date Operation Summary # 1 5.0 9/6/2010 9/7/2010 215,939.00 Well Test: 85 BO & 798 BW. Inj gas @ 1457 MCF. Csg Press @ 830 psi. Lifting on GLV 9/13. Rpt No. Start Date Report End Date Daily Cost Total Cum Cost To Date Operation Summary # 1 6.0 9/13/2010 9/1412010 215,939.00 Well Test: 85 BO & 742 BW. Lift Gas 1321 MCF. Csg Press @ 820 psi. Rpt No. Start Date Report End Date Daily Cost Total Cum Cost To Date Operation Summary # 1 7.0 9/17/2010 9/18/2010 215,939.00 Well Test: 86 BO & 69 BW. Lift Gas 1 33 2 MCF. Csg Press @ 820 ps i. Rpt No. Start Date Report End Date Daily Cost Total Cum Cost To Date Operation Summary # 1 8.0 10/2/2010 10/3/2010 215,939.00 Well Test: 98 BO, 656 BW & 18 MCF. Lift Gas 1359 MCF. Casing Press @ 810 psi. FINAL REPORT. III — - -- - -- - -- - — - -- I'. 'I ; III I) i I li i, I li www.xtoenergy.com Page 2/2 Report Printed: 10/18/2010 r PLF 5 -27 -10 9ENT G Y Current Completion KB: 35 Water Depth: 73' MSL C42 -23 Coo Tbg: 3 -%" 9.3# L80 8rd EUE surf - 8,525' Cook Inlet, Alaska 2 -7/8" 6.5# L80 8rd EUE 8,525 - 9,364. Leg 4, Conductor 25 Set: 5 -4 -2005 API No.: 50- 133 -20315 Spud: 3 -13 -78 3 -' /2' Baker TE5 SSSV (2.81" ID) @ 297' X -over 3 -' /z' 9.3# 8rd to 2 -7/8" 6.5# L80 8rd @ 8,525' 2 -7/8" X Nipple (2.313" ID) 9Cr @ 9,154' 6' Pup Jt, 2 -7/8" 6.5# L80 8rd EUE @ 9,155' Surf Csg: 13 3/8 ", 54.5/61 lb, K55. Baker K Anchor @ 9,161' Baker 5 -%" SABL -3 Perm Packer @ 9,162' Set @ 2,578'. Cmt w/ 2,100 sx. 6' Millout Extension @ 9,166' X -over MOE Box X 2 -7/8" 6.5# 8rd Pin @ 9,172' 4' Pup Jt, 2 -7/8" 6.5# L80 8rd EUE @ 9,172' 2 As tbg 2 -7/8" 6.5# L80 8rd EUE @ 9,176' 6' Pup Jt, 2 -7/8" 6.5# L80 8rd EUE @ 9,239' 2 -7/8" GLM w/ Equalizing Valve @ 9,246' Intermediate Csg: 7 5/8" 29.7/33.7 lb, 4' Pup Jt, 2 -7/8" 6.5# L80 8rd EUE @ 9,253' 6' Pup Jt, 2 -7/8" 6.5# L80 8rd EUE @ 9,256' N80. Set 8,822 Cm w/ 4 x Cmt 50 s . @ -7/ " M Sleeve 2. 1 Baker 2 8 C U S " ID 9 S e 3 3 TOC ±6 642'. @ � 4' Pup t 2 -7/8 6.5# L80 8rd EUE P " @ 9 2 As tbg 2 -7/8" 6.5# L80 8rd EUE @ 9,270' 8' Pup Jt, 2 -7/8" 6.5# L80 8rd EUE @ 9,333' Baker Locator w/ 7' Bonded Seals @ 9,341' Baker 5 -' /z' Model F Perm Packer (45 -30) @ 9,342' Baker 5' SBE @ 9,344' X -Over Acme Box X 2 -7/8" 6.5# 8rd Pin @ 9,348' 8' Pup A, 2 -7/8" 6.5# L80 8rd EUE @ 9,349' 2 -7/8" XN Nipple (2.205" ID) 9Cr @ 9,357' 4' Pup A, 2 -7/8" 6.5# L80 8rd EUE @ 9,359' WLREG @ 9,364' GR -GS: 8,654'& 8,689' (2 holes) SQZ'd w/ 70 sk on 4- 25 -05. Prod Liner: 5 -1/2 ", 17 lb, N80. Set @ 9,848'. TOL @ 8,624'. HK -HN: 9,196'- 9,215' Cmt w/ 210 sx. Sqz TOL w/ 150 sx. GLM MD TVD PORT Psc Pso #1 1888 1855 10 920 955 HK -HN: 9,260' - 9,332' #2 3139 3008 12 910 954 #3 4236 4007 12 900 934 #4 5088 4805 16 890 931 #5 5601 5293 16 880 915 H N -H R: 9,367'-9,503' #6 6078 5749 16 870 905 #7 6562 6204 16 860 893 #8 7039 6653 16 850 883 HR -HZ: 9,527'- 9,603' #9 7519 7108 16 840 872 #10 7972 7538 16 830 855 #11 8356 7901 16 820 844 HR -HZ: 9,604'- 9,667' #12 8783 8308 20 810 838 #13 9143 8648 20 ORIFICE Fish: GLV on btm (3- 24 -07) FILL: 9,724 MD (4 -6 -10) PBTD: 9,753' MD (9,161' TVD) TD: 9,850' MD (9,306' TVD) J • ~~Q~~ Oo ~ p~G1~~{Q /.E,.Po,~..oo~.~. Maria L. Perez Regulatory Analyst ~~ XTO Energy, Inc. r ~~ ~ ~.:~ ~ L ~ ` .~ ~.C11.; 200 N. Loraine, Suite 800 Midland, TX 79701 (~ • ~ ~~ ~~ 0 Re: MGS Field, E, F, G Oil Pool, MGS #C42-23 Sundry Number: 310-200 Dear Ms. Perez: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. Chair DATED this ~ day of June, 2010. Encl. • TO ENERGY June 28, 2010 Alaska Oil and Gas Conservation Commission Attn: John Norman, Commissioner 333 W. 7~' Ave., Suite 100 Anchorage, Alaska 99501 Re: Form 10-403, Request for Sundry approval Objective: Coil tbg acid stimulate HN-HZ perfs.. Middle Ground Shoal #C42-23 Middle Ground Shoal Oil Pool Cook Inlet, Alaska API 50-733-20315-00-00 Ladies and Gentlemen; • XTO Energy Inc. hereby submits its Application for Sundry Approval to coil tbg acid stimulate HN-HZ perfs. Attached is the following information for your files: 1. Form 10-403 Application for Sundry Approval. 2. Proposed job procedure. 3. Present wellbore schematic If you required additional information, please contact me at A/C 432-620-4325. Sincerely, ~~°~,~-~ Maria L. Perez, Regulatory Analyst Copy to: Paul Figel, Engineering Manager Tim Smith, Manager Reservoir Dev., Permian Basin 200 N. LORAINE, SUITE 800, MIDLAND, TEXAS 79701 I~ci[yJ~ R~r~Q~i3o~Lo ~o ,.. ~.1 a .~ 4' STATE OF ALASKA ~Als$ka Oil ~ ~111~ ~+~~~• C~~-nsS~Q~n ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS ~~.?~~r~,~~~: on eer oG osn 1. Type of Request: Abandon ^ Plug for Redrill ^ Perforate New Pool^ Repair Well ^ Change Approved Program ^ Suspend ^ Plug Perforations^ Perforate^ Pull Tubing ^ Time Extension ^ Operations Shutdown ^ Re-enter Susp. Well ^ Stimulate ® Alter Casing ^ Other: ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: XTO Ener InC. Development ® Exploratory ^ 178-0240 ' 3. Address: 200 N. LOralne, Sulte 800 Stratigraphic ^ Service ^ 6. API Number: Midland, Texas 79701 so- 733-20315-00-00. 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ^ No ® Middle Ground Shoal 46C42-23 9. Property Designation (Lease Number): 10. Field/Pool(s): =- ~ ~~ ~ % ~ C ADL 18756 is Middle Ground Shoal r ~ ~~>~~~> 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): 98501 9306 9753 9161 NA NA Casing Length Size MD ND Burst Collapse Structural Conductor surface 2578' 13-3 8" 2578' 24 2' 2 Intermediate 8822' 7-7/8" 8822' 8346' 4790 psi 6890 si Production Liner 1224' S-1/2" 8624-9848' 9304' 7740 si 6280 si Perforation Depth MD (ft);i << Perforation Depth TVD (ft): Tubing Size: Tubing Grade: 9.3 & 6.5~~ Tubing MD (ft): 9196-9667' 8693'-9134' 3-1/2 & 2-7/8" L80~ 8rd 9364 Packers and SSSV Type: faker ABL Perm Packers and SSSV MD (ft) and TVD (ft): / Baker Model F Perm 9162' & 9342' 12. Attachments: Description Summary of Proposal ~ 13. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ® Service ^ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: Aug. 1St thru 25rh, 2010 Oil ~ Gas ^ WDSPL ^ Suspended ^ 16. Verbal Approval: Date: WINJ ^ GINJ ^ WAG ^ Abandoned ^ Commission Representative: GSTOR ^ SPLUG ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Maria L . Pere z Printed Name Maria L. Perez Title Regulatory Analyst Signatur ~~ Phone Date 432-620-4325 6/28/2010 COMMISSION USE ONLY Sund Number: 3 ~ ~ ~~ ti it l if i i th t t N C ry a represen ve may w ness : y omm on so a a Conditions of approva ot ss Plug Integrity ^ BOP Test ~ Mechanical Integrity Test ^ Location Clearance ^ Other. ~ ~ ~.`~ D 0 I r'- ~'0 S O 00 P tit Subsequent Form Required: 1 ~ _ G{~(„f APPROVED BY L / ~ Approved by: COMMISSIONER THE COMMISSION // Date: N'' V RBDMS Form 10-403 Revised 1/2010 '~`o"~~ ORIGINAL ~ ~-~~- ~G Submit in Duplicate ~ ~ ~TO ENERGY XTO Energy Inc. MGS C42-23 COOK INLET, ALASKA COIL TBG CLEANOUT AND ACID STIMULATION PROCEDURE WELL DATA: SURFACE CASING: 13-3/8" 54.5, 61# K55. Set @ 2,578'. Cmt w/ 2,100 sx. INTERMEDIATE CASING: 7-5/8" 29.7, 33.7#, N80. Set @ 8,822'. Cmt w/ 450 sx. PRODUCTION LINER: 5-'/2" 17#, N80, @ 8,624 - 9,848'. Cmt w/ 210 sx. Sqz liner top w/ 150 sx. TUBING: 3 1/z" 9.3#, L80 8rd Surface to 8525' 2-7/8" 6.5# , L80 8rd 8525 - 9364' PACKERS: 5-1/2" Baker SABL-3 Perm Pkr @ 9162' 5-1/2" Baker Model F Perm Pkr @ 9342' PERFORATIONS: GR-GS: 8,675 & 8,679' Cmt Sgz'd 4-25-OS HK-HN: 9,196 - 9,215' Isolated behind tandem Pkrs HK-HN: 9,260 - 9,332' Isolated behind tandem Pkrs HN-HR: 9,367 - 9,503' HR-HZ: 9,527 - 9,603' HR-HZ: 9,604 - 9,667' NET PAY: 275' MAX HOLE DEVIATION: 25 Degrees BHST: 160 Deg F BHP: 5,000 psi SMALLEST H): XN Nipple: 2.205" ID @ 9357' CURRENT PROD: Prod @ 15 BOPD & 66 BWPD as of 6-16-10 OBJECTIVE: Coil tb~ acid stimulate the HN-HZ. , NOTE: • Last WL run on 4-6-10 encountered scale @ 9163' to 9397'. Fill was tagged @ 9,724'. • AFE # 100371 • Heat FIW to f100°F • SD gas lift 2-3 days prior to MIRU CTU. Procedure 6-16-10 XTO Energy Inc. • MGS C42-23 Cook Inlet, Alaska • 2 Materials Required: • 10,000 gal (238 bbl)10% HCL DAD Acid (25% xylene) • 80 bbl Gel Pill (2#/bbl Flo-Visc + 3 gal Greencide) (Provided by MI) • 600 bbl 3%KCL FIW Water - 50 gal J313 Friction Reducer (SLB) - 6,000 lbs Powdered KCL (1000 lbs KCL /100 bbl FIW for 3%) (Provided by MI) • N2 bottles to purge reel after job or N2 unit • 3,000 lbs Soda Ash (Provided by MI) • 100 gal Nalco EC6079A Scale Inhibitor Equipment Required: • 1.75" CTU • 1 ea HP Triplex Pump • Filter Skid (3-5 micron) • Plastic Lined Acid Tank for 250 bbl • 250 bbl PTS Flowback Tank - Mud Pump to be tied into tank to pump load to A44-11 Disposal Well - Install 2" line from tank top to production header for gas lift @ EOJ • Return line w/ choke manifold to 250 bbl Surge Tank & to Production Facilities - Manifold to contain a sample catcher to monitor fluids pH - Send "clean" returns to Production Facilities - Send live acid and or fluids containing scale or solids to Flowback Tank DAD Acid Svstem to contain these additives: • 10%HCL • 250 gpt Xylene • 4 gpt A261 Corrosion Inhibitor • 8 gpt L63 Iron Reducer • 5 ppt A 179 Iron Reducer Activator • 20 ppt L41 Iron Chelating Agent • 15 gpt U74 Dispersing Agent • 5 gpt W60 Anti-sludge • 5 gpt W54 Non-Emulsifier • 5 gpt F 103 Surfactant Procedure 6-16-10 XTO Energy Inc. • • MGS C42-23 Cook Inlet, Alaska PROCEDURE: MIRU Schlumberger 1.75" Coil Tbg Unit. RU a filter skid between the mud pits & HP triplex. RU the PTS tank to handle all returns. Install press gauges on the CT, CT Annulus, & 3-1/2" prod tbg annulus. Make up S °leBlaster Tool. Contact the AOGCC 24 hrs prior to BOP test. Press test all ~ lines & BOP's t ,000 '~. Max Press = 4,000 psi. CTU operator to ensure all tools to be calipered before RIH. Sma D = 2.205" XN Nipple @ 9357' 2. Conduct a pre job safety meeting with all SLB & XTO platform personnel. CLEAN OUT HOLE: 3. Open the CT annulus. RIH w/ CT @ 60 fpm while pumping @ 1.5 BPM slick 3% KCL FIW. Slow rate to 5 fpm when passing over the Gas Lift Mandrels (See Attached WBD) and make 2 passes. Continue to RIH @ 60 fpm to 9100' where scale was encountered with WL. 4. Jet Wash the prod tbg from 9100 - 9364' (EOT) @ 10 fpm @ 1.5 BPM w/ slick 3%FIW. Use acid only when necessary to get past tight spots. (Divert acid back to Flowback tank when necessary.) From EOT @ 9364', cont DH @ 10 fpm to PBTD @ 9753' pumping 3%FIW @ 1.5 BPM. 6. Tag up @PBTD or as deep as possible. Circ hole clean w/ 20 bbl Flo-Visc pill followed with 80 bbl slick 3%FIW @ 1.5 BPM. ACID SPOT & SOAK: 7. Pull up to 9700'. Lay 325 gal (7.7 bbl) 10% acid from 9700' to 9367' while PUH using slick 3% FIW to displace. PU CT to 9100' & SD. Let acid soak for 30 min. 8. RIH @ 10 fpm to 9700' while circ slick 3%FIW @ 1.5 BPM. At 9700', circ hole clean w/ 20 bbl Flo-Visc pill followed with 80 bbl slick 3%FIW. Send acid returns to the Flowback Tank. ACID WASH PERF'S: ~` 9. Acid wash perf s 9667 - 9367' w/ 1900 gal (45 bbl) 10% acid @ 1.5 BPM, moving the CT @ 20 ft/min. Make 1 pass up & 1 down. 10. RIH to TD. Circ hole clean w/ 20 bbl Flo-Visc gel pill followed with 80 bbl slick 3%FIW @ 1 BPM. Do NOT mix any friction reducer to FIW beyond this step. ACID INJECTION JOB: ~ 11. SI the CT annulus. Inject 7500 gal (180 bbl) 10% acid while making 5 passes across the interval from 9680 - 9365' while pumping @ 0.75 BPM and moving the CT as slow as possible ~5 ft/min. Finish pumping all acid @ 9365'. 12. Open the CT annulus. Circ 2-3/8" x 3-1/2" tbg clean of acid with 80 bb13%FIW. Check pH & close CT annulus. Procedure 6-16-10 • XTO Energy Inc. ~ • 4 MGS C42-23 Cook Inlet, Alaska 13. Mix 100 gal Nalco EC6079A Scale Inhibitor in 180 bb13% KCL FIW (no friction reducer). Over displace acid with 180 bb13%FIW + Scale Inhibitor while making 6 passes across the interval from 9680 - 9365' while pumping @ 0.75 BPM and moving the CT @ 5-10 ft/min. 14. Open CT annulus. POOH with coil tbg @ 100 fpm. Close the Swab valve. Bleed off press. RD CTU. 15. Slowly start up gas lift taking returns to the PTS tank. Cont to flow into PTS tank until pH is neutral (7). Switch returns into production header & start testing well. Record any use of the disposal well with fluid type, volume and injection rates & press. Overflush by 125 bbl FIW at end of disposing fluids. Paul Figel Engineering Manager Kyle Hammond Vice President Operations Procedure 6-16-10 ~~ ENERGY ~; MGS C42-23 Cook Inlet, Alaska , Leg 4, Conductor 25 `~% API No.: 50-133-20315 Spud: 3-13-78 Surf Csg: 13 3/8", 54.5/61 Ib, K55. Set @ 2,578'. Cmt w/ 2,100 sx. Intermediate Csg: 7 5/8" 29.7/33.7 Ib, N80. Set @ 8,822'. Cmt w/ 450 sx. TOC @ ±6,642'. KB: 35' Water Depth: 73' MSL PLF 5-27-10 Tbg: 3-%2' 9.3# L80 8rd EUE surf - 8,525' 2-7/8" 6.5# L80 8rd EUE 8,525 - 9,364'. Set: 5-4-2005 3-'/" Baker TE5 SSSV (2.81" ID) @ 297' X-over 3-'/i' 9.3# 8rd to 2-7/8" 6.5# L80 8rd @ 8,525' 2-7/8" X Nipple (2.313" ID) 9Cr @ 9,154' 6' Pup Jt, 2-7/8" 6.5# L80 8rd EUE @ 9,155' Baker K Anchor @ 9,161' Baker 5-'/2' SABL-3 Perm Packer @ 9,162' 6' Millout Extension @ 9,166' X-over MOE Box X 2-7/8" 6.5# 8rd Pin @ 9,172' 4' Pup Jt, 2-7/8" 6.5# L80 8rd EUE @ 9,172' 2 Jts tbg 2-7/8" 6.5# L80 8rd EUE @ 9,176' 6' Pup Jt, 2-7/8" 6.5# L80 8rd EUE @ 9,239' 2-7/8" GLM w/ Equalizing Valve @ 9,246' 4' Pup Jt, 2-7/8" 6.5# L80 8rd EUE @ 9,253' 6' Pup Jt, 2-7/8" 6.5# L80 8rd EUE @ 9,256' Baker 2-7/8" CMU S Sleeve (2.313" ID) @ 9,262' 4' Pup Jt, 2-7/8" 6.5# L80 8rd EUE @ 9,266' 2 Jts tbg 2-7/8" 6.5# L80 8rd EUE @ 9,270' 8' Pup Jt, 2-7/8" 6.5# L80 8rd EUE @ 9,333' Baker Locator w/ 7' Bonded Seals @ 9,341' Baker 5-'/" Model F Perm Packer (45-30) @ 9,342' Baker 5' SBE @ 9,344' X-Over Acme Box X 2-7/8" 6.5# 8rd Pin @ 9,348' 8' Pup Jt, 2-7/8" 6.5# L80 8rd EUE @ 9,349' 2-7/8" XN Nipple (2.205" ID) 9Cr @ 9,357' 4' Pup Jt, 2-7/8" 6.5# L80 8rd EUE @ 9,359' WLREG @ 9,364' GR-GS: 8,654' & 8,689' (2 holes) SQZ'd w/ 70 sk on 4-25-05. Prod Liner: 5-1/2", 17 Ib, N80. Set @ 9,848'. TOL @ 8,624'. Cmt w/ 210 sx. Sqz TOL w/ 150 sx. Current Completion i% ~,;,; :- 'F ~;; GLM MD TVD PORT PSC PSO #1 1888 1855 10 920 955 #2 3139 3008 12 910 954 #3 4236 4007 12 900 934 #4 5088 4805 16 890 931 #5 5601 5293 16 880 915 #6 6078 5749 16 870 905 #7 6562 6204 16 860 893 #8 7039 6653 16 850 883 #9 7519 7108 16 840 872 #10 7972 7538 16 830 855 #11 8356 7901 16 820 844 #12 8783 8308 20 810 838 #13 9143 8648 20 ORIFICE ii HK-HN: 9,196'-9,215' HK-HN: 9,260'-9,332' H N-H R: 9, 367'-9, 503' HR-HZ: 9,527'-9,603' HR-HZ: 9,604'-9,667' Fish: GLV on btm (3-24-07) FILL: 9,724 MD (4-6-10) PBTD: 9,753' MD (9,161' TVD) TD: 9,850' MD (9,306' TVD) . Reviewed By: Safety Valve & Well Pressures Test Report P.1. Suprv % ~ z ~~~ Comm Pad: MGS_XTO_C_PLATE InspDt: 2/22/2008 °~Inspected by John Crisp Interval InspNo svsJCr080225134306 Related Insp: Field Name MIDDLE GROUND SHOAL Operator XTO ENERGY INC Operator Rep Barney Phillips Reason 90-Day `~ _ --y ~ Sre: Inspector --_ ---- _ __, I -_ _ Fi~ell Data ~ Pilots ~ ~ SSV ~ SSSV Shutlrt D~ Well Type ~ ..Well Pressures ~ Gas Lift Waiver __ Comments Well ~ Permit Separ Set UP Test Test Test Date Sl Ot1,WAG,GINJ, Inner Outer Tubing Number Number PSI PSI Trip Code Code Code GAS.CYCLE- SI Pct Pci pcr vo~ini., ve.•ini,. ~ C12-23 -- - - - Cl3 23 - 1900200 - -- 1880990 68 --- 68 37 ~ 37 - 37 ~ 37 ~ P P P P ~p - P ---- 1-01L - ---- 1-0[L - ----~ -- ---- -. --- - 1- _ - -- - _- - - -- -- --- C 13 A 23 -_ L - 1901060 G8 0 ~_ T P P ----- - 1 OIL f - - ' - _ ~ . - _ -- ~- -- -- - -- C21 23 ; _ _, C2l 26 1890870 _ 1890040 ~ 68 68 I 0 ~ I ~ 0 i I p P I -- P -- --- - - i-OIL I-O[L - - ~ _ - --- - -.-- ---- ~_ - ---- - - -~ -- I - - --- __----- - SSSV out for W/L work - ---- -~ -- - - C21A 23 C22-26RD ' 1910440 i 1760650 ' 68 ~ 8 0 j ~ -- -- I P ~--- ~ P - -- - 1-OIL - - --- ~ _~ t ~ ---- r- --- - ~ - -t - -- _-- - - - ---' --- - - - ---- ----1 C22A-26LN I C31-26RD -2041820 - 2041400 6 68 - 68 0 - 0 - ~ 0 i - P P P P -- ~ , --~ t-OIL _ _ l-OIL - - ---- I ~ - -- T _. - - - - - -- - --- - ---. J - --- -- - ------- -_ C32-23LW C42-23 -- 2020340 1780240 --- 68 ~ 68 I 0 -- ~ -- P ---- P P P - a i ~ l -OIL - I-OIL i - -T ~ - _ -~ - - --~ i --- C43-14 --- - l 881320 ~ 68 ~ - 0 ~--J - P P _ _P_ L_ P ---~ t-OIL _i _OIL -.. - ~ _-~ _ . -~ ~ _ _ -_ ~ -_--- ~ • Comments Performance Pilot numbers listed on wells C 12-23 & C 13-23 are fur the pilots on the separators. Individual wells are r ~ -- --------- not equiped with pilots on this platform. / P Wells Com onents Failures Failure Rate I `~ 12 25 0 ti~~~~~~ MAR '~ ZU~ • Tuesday, February 26, 2008 I ) ) ~TO J':NkRGY XTO Energy Inc. 200 North Loraine Suite 800 Midland, Texas 79701 432-682-8873 432-687-0862 (Fax) June 6, 2005 \ l~>'ödJt RECEI\/ED JUN 0 8 Z005 Alaska Oil and Gas Conservation Commission Attn: Mr. John Norman 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 RE: Well Completion Report: Well C42-23 .l\lssk; Oil &. ~..I.murus~mu~ ArlChçrCloQ Dear Mr. Norman, XTO Energy, Inc. hereby submits its Report of Sundry Well Operations (Form 10-404) for the workover performed on the C42-23 on Platform C, in the Middle Ground Shoal Field of Cook Inlet, AK. The test holes that were shot in 1986 in the GR-GS were cement squeezed. The well was stimulated with a slick water - acid fracture treatment in the HN & HR intervals & completed with straddle packers over the HK. The well is currently producing from the HN & HR @ 89 BOPD, 355 BWPD & 40 MCF versus the previous completion that had all 4 zones open: GR, HK, HN & HR @ 30 BOPD, 472 BWPD & 36 MCF. Please find attached the following information for your files: SCANNED ~tUN 1. L1 2005 1. Form 1 0-404 Well Completion 2. Daily W orkover Reports 3. Present Wellbore Schematic If you have any questions or require additional information, please contact me at (432) 620-6743. Sincerely, 9J.J. Y Paul L. Figel Engineering Manager Cc: Scott Griffith Tim Smith C~\ r"" ¡ r-. ~ f\f A L j¡,·<¡tJli~ ALA~ )OIL AND ~:AST~g~S~L:;:~ON COMMlùJION REPORT OF SUNDRY WELL OPERATIONS RE(~EIVED JUN 0 8 2005 Plug Perforations ~ Perforate New Pool D Perforate D 4. Current Well Class: Development [2] Stratigraphic D 1. Operations Abandon U Performed: Alter Casing D Change Approved Program D 2. Operator XTO Energy Inc. Name: RepairWell U Pull Tubing [2] Operat. Shutdown D 3. Address: 200 N. Loraine, Ste 800, Midland, Tx 79701 7. KB Elevation (ft): 35' 8. Property Designation: ADL 18756 11. Present Well Condition Summary: Total Depth measured 9850 feet true vertical 9306 feet Effective Depth measured 9753 feet true vertical 9161 feet Casing Length Size MD Structural Conductor Surface 2578' 13-3/8" 2578' Intermediate 8822' 7-5/8" 8822' Production Liner 1224' 5-1/2" 9848' Perforation depth: Measured depth: 9196-9667' True Vertical depth: 8696-9134' Tubing: (size, grade, and measured depth) 3-1/2" & 2-7/8" Packers and SSSV (type and measured depth) Baker 5-1/2" SABL-3 9162' StimulateL::J AlasktatAd:l~ ª-ß~s Con~. CÚiHirn$~iíJ.;l Waiver D Time Extension []nchorage Re-enter Suspended Well D 5. Permit to Drill Number: Exploratory D 178-0240 Service D 6. API Number: 50-733-20315 9. Well Name and Number: C42-23 10. Field/Pool(s): Middle Ground Shoal Plugs (measured) Nt A Junk (measured) N/ A TVD Burst Collapse 2492' 2730 psi 1130 psi 8346' 4790 psi 6890 psi 9304' 7740 psi 6280 psi L80 3-1/2" @ 8525' & 2-7/8" @ 9364' Model"F" pkr 9342' Baker TE5 SSSV 297' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Cmt squeezed GR-GS wno sxs. Stimulate HN & HR: 9367-9667' Treatment descriptions including volumes used and final pressure: Stimulation w/71 bbls 10% HCL w/1 0% xylene & 475 bbls 20# linear gel @ 8 BPM @ 6000 psi 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casing Pressure 36 472 620 40 355 790 15. Well Class after proposed work: Exploratory D Development [2] 16. Well Status after proposed work: Oil[2] Gas D WAG D 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Prior to well operation: 30 Subsequent to operation: 89 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations x Tubing Pressure 100 70 Service D GINJ 0 WINJ D WDSPL Sundry Number or N/A if C.O. Exempt: 305-050 D Contact Paul Figel RBDMS 8Fl JUN 0 8 2005 Printed Name Paul Figel Signature 9w #.. ¥ Form 10-404 Revised 04/2004 Title Engineering Manager Phone 432-620-6743 Date 6n /2005 UK\G\NAL Submit Original Only ) ) 1 XTO Energy Inc. C42-23 Daily Workover Report ...... ..... .. l~I() ·.:;IWJ;'RJ~J,;~::~jf~I:!~';" . Objective: Recomplete & Acid Prac Well First 04/16/2005 Report: 4/16/05 Rig accepted @ 0600 hrs. Rigged up slickline, ran 2.70 gauge ring. Unable to pass 7,735'. POOH. Ran 2.60 gauge ring. Unable to pass 8,045'. POOH. Ran & pulled on third attempt valve from #5 GLM. Rigged dn slickline. Pinished building 3% KCL fluid. Rigged up mud line. Circ 3% KCL wtr through GLM @ 7,596'. Monitored well. No press build up and no flow. Set BPV, nipple dn tree. While nippling dn annulus started flowing. Shut in 5 mins, 25 psi. Attempted to bleed dn, still flowing after 20 mins. Shut in 10 mins, 25 psi. Rigged up to circ. 4/17/05 Rigged up to circ. Circ w/returns to pmp tbg volume, ck'd flow, pmpd additional 20 bbls. Monitored well, flowed from annulus, when closed in - BPV leaking by, left annulus open, pulled BPV, no flow from tbg w/annulus flowing, rigged up lines to take returns to pits through choke. Circ well. Monitored well. Small flow from annulus, no flow from tbg. Set BPV, nipple dwn tree (tree studs rusted into well head, unable to pull, cut studs between flanges. pulled and LD tree. Lowered riser & nipple up BOP's. Attempted tst. Appears to be leaking past hanger. After discussion, no plug installed in hangers heck for ball valves control line, LD tst joint. 4/18/05 Removed drlg nipple, break flange @ wellhead, lift stack, installed control line plug in hanger & lwr stack made up wellhead flange. Tstd BOP's 250 & 5,000 psi. Hydril to 250 & 2,500 psi. Accumulator tst & gas alarms (tst witnessed by Jeff Jones of AOGCC). Made up drill pipe & pup jt to pull & pulled to 170,000#. Pkr released. Pulled hanger to floor. Circ hole volume through choke. Monitored well-flowing, shut in weight up pits to 8.9 ppg. Circ 8.9 ppg. Monitored well, no flow, pmp dry job, LD hanger, pulled & LD tbg, slow excessive drag, pkr hung up @ 8,459' (rec 2 jts & 2 pup jts, moved pkr up hole 116). Attempted to free up pkr w/pull, torque & pmp press - no movement. Rigged up APRS to cut tbg. 4/19/05 Prepping for coil tbg equipment. APRS WL RIH w/2.59" Jet Cutter. Unable to pass 5,853'. POOH w/Cutter. Rlli w/2.50" gauge ring, weight bars & jars. Unable to get past 6,183'. POOH w/gauge ring, RD APRS WL. Monitored well. Prepped decks & rig for coil tbg equipment. Changed valves & seats on #2 mud pmp. Changed leaking butterlly valve in pmp room. Repaired stand pipe bleeder valve, cleaned & organized rig floor, sub-base & wellhead room. 4/20/05 Monitored well, readied decks & rigged for coil tbg equip. Offloaded BJ Coil Equip & personnel from boat - PJSM - spotted & rigged up coil tbg. ) ) 2 4/21/05 Rigged up BJ Coil Tbg. Filled coil w/9.0 ppg FIW, pmpg pig. Tstd coil tbg BOP's to 250/5,000 psi (Jim Regg w/AOGCC waived witness). Made up tbg connection, pulled tst, made up BHA w/mtr & 2.75 mill. CO 3-1/2" tbg w/2.75 mill to 8,550' (brought FIW weight to 9.1 to stop .3 bbl/hr flow). Circ, pmpd 20 bbls high vis sweep. POOH w/coil, broke off lubricator, broke off mill & rigged coil aside. Rigged up APRS & PJSM. RIH w/2.59 jet cutter @ 7,400' collar locator. Stopped working, POOH & checked tools. 4/22/05 Chg'd out collar locator. Rill w/jet cutter, shot @ 8,449'. POOH, shot fired, rigged dwn APRS, LD coil tools, stab lubricator-blow dwn coil & rigged dwn BJ coil equipment. Circ, back loaded coil equipment & off loaded cmt equipment. POOH, LD tbg, ball valve & GLM's (recovered 283 jts 3-1/2" tbg, ball valve, 2 pups & 7 GLM). 4/23/05 Rigged dwn tbg equip, cleaned rig floor, made up wash over mill, scraper assembly, PU 9 DC's & RIH wllO stands. Cut & slipped drlg line. Rill w/mill & scraper assembly to 8,319'. Closed Hydril, reversed circ & washed dwn fr/8,319' to 8,447'. Reversed btms up @ 8,350', 8,410' & 8,447' to CO fill opened Hydril. Washed over & milled on pkr @ 8,447'. POOH w/mill & scraper assembly. LD mill assembly, PU overshot assembly & RIH w/overshot. ~.;..: .l .,u""" "..:~;:::::::Mi::;::;~;¡(¡¡':""""" 4/24/05 Rill w/overshot to 8,380'. Workover tbg stub @ 8,440', milled over stub, latched onto fish. Worked pkr loose & PU 180', swabbed. Circ high vis sweep, worked pipe 90'. POOH w/fish. LD DC's. LD fish (cut off tbg pup, XO, pkr, X-nipple, 1 jt tbg, X- nipple, pup jt, mule shoe) LD fishing tools. Made up scraper assembly (5-1/2" & 7- 5/8"). RIH to 9,587'. Washed dwn, tagged top 5-1/2" liner w/7-5/8" scraper @ 8,624' (4-3/4" mill & 5-1/2" scraper @ 9,758'). Circ high vis sweep. POOH & LD scrapers. Rigged up tst tools. 4/25/05 Tstd BOP's to 25015,000 psi, Hydril to 250/2,500 psi. Accumulator tst, tstd gas alarms & rigged dwn test tools. Set wear ring. Rigged up APRS, PJSM & Rill w/bridge plug. Correlated with bridge plug @ 8,724'-fire, plug did not set, POOH. Ck'd tools & make up, Rill, correlated, set bridge plug @ 8,724', POOH, rigged dwn APRS. Made up retrievamatic for 7-5/8" & tail, RIH w/tail @ 8,450'. Set pkr @ 8,347', tested by press up annulus to 500 psi, ok. Rigged up cmt lines, PJSM, maintained 500 psi on annulus. Pmpd 3 bbls 9.0 ppg FIW, tested lines to 6,000 psi, established injection rate @ 1 bbl/min, 4,180 psi, shut dwn & bled off press. Released pkr. RIH w/tail @ 8,700'. Pmpd & spotted 4 bbls 10% HCL acid, pulled up & set pkr @ 8,347', tail @ 8,450', press up annuls to 500 psi. Established injection rate & over displaced acid w/50 bbls 9.0 ppg, 1 bbllmin 4,200 psi. Batched up 70sx Class "G" cmt w/.4% FL-63+ .3% CC- 32+ .05% ASA-301+ .15% R-3, 14 bbls of 15.8 ppg wll.15 yld. Released pkr, pmpd 10 bbls FW, 14 bbls cmt, 10 bbls FW, 67 bbls 9.0 ppg FIW, holding 200-300 psi back press on annulus, 3 bbls/min 180 psi, set pkr, maintained 500 psi on annulus, continued displacing w/26.5 bbls, 9.0 ppg FIW, 1 bbllmin 3,800 psi w/93.5 bbls total displaced, hesitated 15 min, pmped .5 bbl fr/3,300 to 4,070 psi, hesitated 15 min, pmpd .25 bbl fr/3,350 to 4,160 psi, hesitated, no press drop in 5 min. Cmt'd in place 0415 hrs, bled ) ) 3 off pressure. Bled off annulus & released pkr, reversed 1.5 drill pipe volume (recovered .25 bbl cmt). Set pkr, press up on cmt to 500 psi, waited on cmt. 4/26/05 Waited on cmt, held 500 psi on cmt. Bled off press, released packer, POOH. Make up 6" bit & RIH to 8,348'. Washed & reamed, cleaned out 7-5/8" csg fr/8,348'-8,624' (top 5-1/2" liner). Circ, POOH, LD 6" bit & make up 4-3/4" mill. Rill. 4/27/05 Rill w/4-3/4" mill to top of 5-1/2" liner. CO 5-1/2" liner to 8,670'. Tstd perf @ 8,654' to 1,000 psi, good tst. Circ btms up. Tst perf @ 8,689' to 1,000 psi, good tst. Drld out bridge plug @ 8,724'. POOH w/CO mill. PU scraper. RIH w/4-3/4" mill & 5-1/2" scraper. Washed 90'to PBTD 9,753'. Circ high vis sweep. POOH. LD drill pipe. 4/28/05 Unloading frac equip. POOH, LD drill pipe. Rigged up to PU frac string. Make up retrievamatic for 5-1/2" & tail. RIH, PU 2-7/8" & 3-1/2" tbg. Off load frac tnks & frac equIp. "" '1--; .- , ~,,~ "''''" 4/29/05 POOH w/4.75 mill & 5-1/2" scraper. PU 1 jt 2-3/8" tbg, Baker Retrievamatic pkr, 24 jts 2-7/8" WTS-6 & 252 jts 3-1/2" WTS-6 tbg. Attempted with no success to get in 5- 1/2" liner @ 8,624' w/pkr. POOH. Cmt found in slips on pkr. MU 4.75" mill, 5-1/2" csg scraper & junk basket. Rill. Washed & reamed thru 5-1/2" liner HRG @ 8,624'.' Pmpd sweep & circ out. Rill to 9,367'. POOH w/mill & scraper. 4/30/05 LD 4.767" mill & string mills @ 9,753' (0'/24 hrs). POOH w/4-3/4" mill, 5-1/2" csg scraper & junk basket. LD BHA & recovered cmt in junk basket. MU Baker retrievamatic pkr. RIH to top of 5-1/2" liner hgr. Circ & worked pkr thru liner hgr. Got below 5-1/2" TOL, pkr was free. Attempted to set pkr, pkr would not set. Had to work pkr both ways thru liner hgr. POOH. LD pkr, left 2 rubber pkr elements & 3 drag blocks in hole. Slips were worn. MU 4.767" mill, pmpd out sub, 4.68" string mill, 4' flex jt, 4.75" string mill, 744' of 2-7/8" WTS-6 tbg & 5.875" string mill. Rill on 3-1/2" WTS-6 tbg. Rill to top of 5-1/2" liner hgr @ 8,624'. Washed & reamed thru liner hgr. RIH to 9,396' w/btm mill. Top string mill bottomed out in liner hgr. Dressed off inside liner hgr. POOH to 8,624', washed & reamed thru liner hgr. Dropped ball to open pmp out sub, never did see sub open. Circ btms up & pmpd dry job. POOH. LD mills. Pump out sub had shifted & was open. 5/1/05 Back flowed well after frac @ 9,753' (0'/24 hrs). LD CO mills. MU Baker Retrievamatic pkr w/4.68" string mill & 2' - 2-7/8" 8rd mule shoe. RIH w/Baker Retrievamatic. Weatherford made up connections. Set pkr @ 9,344'. Tstd dn tbg to 900 psig (held psi no returns on annulus) press tstd annulus to 900 psi (held psi no returns up tbg). Released pkr, rigged up BJ. Press tstd BJ lines to 4,700 psi, pmpd 500 gal 10% HCL pickle acid & displaced to within 500' of btm of tbg. Closed BOP, rev acid to 250 bbls. Tank neutralized acid w/soda ash. BJ displaced tbg w/70 bbls of clean filtered wtr. Reset pkr @ 9,344'. Tstd frac lines to 9,000 psi. Injected & broke dn formation w/4,000 psi & established injection rate of 9.5 BPM @ 8,600 psi & 5.5 BPM @ 4,850 psi. Pmped a total of 23 bbls wtr. SD. ISIP = 3,500 psi (FG=0.85 psi/ft). Frac'd HN perfs: 9,367'-9,503' & HR perfs: 9,527'-9,667' w/71 bbls 10% HCL w/lO% xylene & ') ) 4 475 bbls 20# linear gel. Avg Rate=8 BPM @ 6,000 psi. PMax=7,400 psi. QMax=10.5 BPM. Dropped 1,000# Sandtrol Sure Vert in 3 stages. Sure Vert is biodegradable pig fat in 8/40 mesh. Stg 1: 24 bbls acid. Stg 2: 12 bbls slick wtr + 0.5 ppa, Diverter (250 lbs). Stg 3: 71 bbls slick wtr. Stg 4: 24 bbls acid. Stg 5: 18 bbls slick wtr +0.75 ppa, Diverter (500 lbs). Stg 6: 53 bbls slick wtr. Stg 7: 24 bbls acid. Stg 8: 12 bbls slick wtr + 0.5 ppa, Diverter (250 lbs). Lost prine on acid frac. Went to flush. Overflushed acid w/125 bbls slick wtr. SD. ISIP = 3,190 psi (FG=0.79 psi/ft). 5 min=267 psi, 10 min=160 psi & 15 min=123 psi. Rigged dn. Flowed back load. Note: Started having communication on backside after 1st acid stg hit perfs. Ann press incr fr/700 psi to 1,200 psi w/WHP @ 5,300 psi. Assume HN perfs communicating w/HK perfs 35' above b/w the pkr. 5/2/05 RllI w/btm pkr on Wireline @ 9,753' (0'/24hrs). Back flowed 273 bbls of fluid. SI well & monitored (no press build up). Rev circ tbg volume. Built mud volume. Circ well w/9.2 ppg (well stable). Moved pkr up hole to 9,240' & set b/w the HK & HN perfs. Pressured up tbg annulus to 1,500 psi, bled off 150 psi in 15 min. POOH. Standing work string back. LD 3 jts of 2-7/8" work string & Baker Retrievamatic. LD string mill & 2-7/8" mule shoe. Tstd BOP's 250-5,000 psi. Rigged up APRS wire line unit. RllI on Wireline w/Baker "FB-l" retainer production pkr w/5' seal bore ext 2-7/8" 8' pup, 2.313" X-N nipple, 2-7/8" 4' pup & 4-3/8" aD w/leg. 5/3/05 Ran 2-7/8" & 3-1/2" completion @ 9,753' (0'/24 hrs). RIH w/Baker FB-l retainer production pkr on Wireline (made 2 trips in hole w/pkr, 1st trip firing head failed). Set pkr @ 9,342'WLM. Rigged dn APRS. RIH w/2-7/8" WTS-6 tbg. POOH LD. RIH w/3-1/2" WTS-6 tbg. LD 3-1/2" WTS-6 tbg. RIH w/Baker seal assembly, 5-1/2" Sabl perm. Pkr on 2-7/8", 6.5#, L-80, 8rd tbg & 3-1/2",9.3#, L-80, 8rd tbg w/GLM's. 5/4/05 ND BOP's @ 9,753' (0'/24 hrs). Fin running 3-1/2" tbg. Spaced out & mixed up 20 bbls Biocide pill. Circ pill dn tbg. Landed tbg as follows: Cameron hgr - 35.1, 8 jts 3- 1/2", 9.3#, L-80, 8rd tbg, TE-5 SSSV - 296.79,51 jts 3-1/2" tbg, GLM #1 @ 1,887.67', 40 jts 3-1/2" tbg, GLM #2 @ 3,138.52', 35 jts 3-1/2" tbg, GLM #3 @ 4,236.02', 27 jts 3-1/2" tbg, GLM #4 @ 5,087.47', 16 jts 3-1/2" tbg, GLM #5 @ 5,601.61', 15 jts 3-1/2" tbg, GLM #6 @ 6,078.34', 15 jts 3-1/2" tbg, GLM #7 @ 6,561.73', 15 jts 3-1/2" tbg, GLM #8 @ 7,038.72', 15 jts 3-1/2" tbg, GLM #9 @ 7,518.72', 14 jts 3-1/2" tbg, GLM #10 @ 7,972.41', 12 jts 3-1/2" tbg, GLM #11 @ 8,356.40', 5 jts 3-1/2" tbg, cross-over 3-1/2" 8rd to 2-7/8" 8rd, 8 jts 2-7/8", 6.5#, L-80, 8rd tbg, GLM #12 @ 8,783.04', 11 jts 2-7/8" tbg, GLM #13 @ 9,142.66', x-nipple w/2.313 profile @ 9,153.49', Baker Model 40FA36 "K" anchor @ 9,160.96', Baker 44 Sabl 36x27 per. Pkr @ 9,161.72', milled out ext @ 9,165.92', 2 jts 2-7/8" tbg, GLM dummy @ 9,245.56', locator @ 9,341.20', seals inside 45-30 FB-1 pkr @ 9,341.70' to 9,347.96', Baker FB-l pkr set on wireline @ 9,342' & 21 - 1/2" SS bands holding control line. Tstd tbg to 1,000 psi for 10 mins. Set pkr & set BPV - N/D BOP's. 5/5/05 Released rig @ 9,753' (0'/24 hrs). Nipple dn BOP's. Nipple up tree & tstd to 5,000 psi. RU & ran slickline, pulled ball rod assembly & RHC plug. Instld safety valve & choke valve on tree. Released rig f/C42-23 @ 0600. ) 5 5/6/05 Finished hooking up flow lines. Started up gas lift. 5/8/05 Well Test: 76 BO, 399 BW & 73 MCF. Inj gas @ 1,224 MCF w/csg press @ 780 psi & WHP=70 psi. Well lifting @ orifice. (Prod from GR-HR prior to workover was 30 BO, 472 BW & 36 MCF). Well is producing from HN & HR w/equalizing valve shut- in on HK b/w pkrs. ~"uu .1._"_' -,.. -.., ".....;w;.,.,.",.,;.;;;m!;¡¡¡~~,..;.::;m) r.;.,~¡;~,Jf,---:,", 5/9/05 Well Test: 62 BO, 364 BW & 12 MCF. Inj gas @ 1,182 MCF w/csg press @ 730 psi & WHP=70 psi. 5/10/05 Well Test: 51 BO, 392 BW & 24 MCF. Inj gas @ 1,182 MCF w/csg press @ 730 psi & WHP=70 psi. . "..... ...:f,."......:::;;::.".......::ø. ...... ............... 'f;.:::-.....,:..~:;::.. .......ff,...... ..::.:f,--,:.:f.:f...-'_'.':." 5/11/05 Well Test: 59 BO, 311 BW & 19 MCF. Inj gas @ 1,141 MCF w/csg press @ 700 psi & WHP=70 psi. 5/12/05 Well Test: 62 BO, 300 BW & 21 MCF. Inj gas @ 1,033 MCF w/csg press @ 685 psi & WHP=70 psi. 5/15/05 Well Test: 59 BO, 287 BW & 25 MCF. Inj gas @ 1,022 MCF w/csg press @ 680 psi & WHP=70 psi. 5/26/05 Well Test: 89 BO, 335 BW & 40 MCF. Inj gas @ 1,022 MCF w/csg press @ 790 psi & WHP=70 psi. ;-^al"'-,;.II"A. --UII_~~ ";-""-T,I 6/2/05 Wireline Report: All depths are WLM unless where noted. RU WL. RIH w/pulling tool to GLM #13 @ 9,148'. Latched & POOH w/orifice valve. Tore dwn valve & inspected. Valve was clean. Put well on gas lift well to clean pocket. Redressed orifice valve. SD gas lift. RIH & set 3/8" orifice valve @ 9,148'. POOH. RWTP. ~TO ~~RGY MGS C42-23 Cook Inlet, Alaska Leg 4, Conductor 25 API No.: 50-133-20315 Spud: 3-13-78 Surf Csg: 13 3/81" 54.5/61 Ib, K55. Set @ 2,578'. Cmt wI 2, 1 00 sx. Intermediate Csg: 75/8" 29.7/33.7 Ib, N80. Set @ 8,8221. Cmt wI 450 sx. TOC @ ±6,642'. Prod Liner: 5-1/2", 17 Ib, N80. Set @ 9,8481. TOL @ 8,6241. Cmt wI 210 sx. Sqz TOL wI 150 sx. GLM MD #1 1888 #2 3139 #3 4236 #4 5088 #5 5601 #6 6078 #7 6562 #8 7039 #9 7519 #10 7972 #11 8356 #12 8783 #13 9143 TVD PORT PSC 1855 10 920 3008 12 910 4007 12 900 4805 16 890 5293 16 880 5749 16 870 6204 16 860 6653 16 850 7108 16 840 7538 16 830 7901 16 820 8308 20 810 8648 24 ORIFICE FILL: None (5-6-05) PBTD: 9,7531 MD (9,161' TVD) TD: 9,850' MD (9,306' TVD) ) Current Completion ~ JJ .J .J .J J .J J J _.",: ~"""".""""",,'I " ,I J ~ Î(2:,.,',f 9J' ~I,·,;·,.·"i.:' 7~ I fI,,';,',',:,':·' ~ I'~' " ; ~ ~,¡. :í} & ~ I I",·,',,, W¿' II.,.,",,' ,I, ,Ii' . ..I", " J J .J / .J pso 955 954 934 931 915 905 893 883 872 855 844 838 J " i','",.,.','.,,"',",', "'.' · ..zI~",'i,:,':,.. ~,.,. ~ ,'/" , :', ,('. ~ ~ I mf~ ~ z'~ I~ J\ ~ ~ ~ ~ m .~ .--. z r ~ ) PLF 6-6-05 KB: 351 Water Depth: 73' MSL Tbg: 3-%" 9.3# L80 8rd EUE surf - 8,52' 2-7/8" 6.5# L80 8rd EUE 8,525 - 9,364'. Set: 5-4-2005 3-%" Baker TE5 SSSV (2.81" 10) @ 297' X-over 3-%" 9.3# 8rd to 2-7/8" 6.5# L80 8rd @ 8,525' 2-7/8" X Nipple (2.313" 10) 9Cr @ 9,154' 6' Pup Jt, 2-7/8" 6.5# L80 8rd EUE @ 9,155' Baker K Anchor @ 9,161' Baker 5-%" SABL-3 Perm Packer @ 9,162' 6' Millout Extension @ 9,166' X-over MaE Box X 2-7/8" 6.5# 8rd Pin @ 9,172' 4' Pup Jt, 2-7/8" 6.5# L80 8rd EUE @ 9,172' 2 Jts tbg 2-7/8" 6.5# L80 8rd EUE @ 9,176' 6' Pup Jt, 2-7/8" 6.5# L80 8rd EUE @ 9,239' 2-7/8" GLM w/ Equalizing Valve @ 9,246' 4' Pup Jt, 2-7/8" 6.5# L80 8rd EUE @ 9,253' 6' Pup Jt, 2-7/8" 6.5# L80 8rd EUE @ 9,256' Baker 2-7/8" CMU S Sleeve (2.313" 10) @ 9,262' 4' Pup Jt, 2-7/8" 6.5# L80 8rd EUE @ 9,266' 2 Jts tbg 2-7/8" 6.5# L80 8rd EUE @ 9,270' 8' Pup Jt, 2-7/8" 6.5# L80 8rd EUE @ 9,333' Baker Locator wI 7' Bonded Seals @ 9,341' Baker 5-W' Model F Perm Packer (45-30) @ 9,342' Baker 5' SBE @ 9,344' X-Over Acme Box X 2-7/8" 6.5# 8rd Pin @ 9,348' 8' Pup Jt, 2-7/8" 6.5# L80 8rd EUE @ 9,349' 2-7/8" XN Nipple (2.205" 10) 9Cr @ 9,357' 4' Pup Jt, 2-7/8" 6.5# L80 8rd EUE @ 9,359' WLREG @ 9,364' GR-GS: 8,654' & 8,689' (2 holes) SQZ'd wI 70 sk on 4-25-05. HK-HN: 9,196'-9,215' HK-HN: 9,260'-9,332' HN-HR: 9,367'-9,503' HR-HZ: 9,527'-9,6031 HR-HZ: 9,604'-9,667' .. ~I"',',.!íJ ð!\~,[,,'Œ' II ! .' . ~ ¡ " I I \ r l -,' ¡ i 1", ¡ f ¡ , U!i U U ; ) (,~u' 'p,! {Æ/}\ n, (Æk' fëù, n.n",","i" ,I'~I'" ¡' 1 ~ J U ! ' lJ' '\\ I r '\ 1J f I ! i i . ¡ I ' : rù)1 lJ\\ r \ , \~ l I. L.:=J,' i "d.." l I,U in ) 17f~ 02e( AI,ASKA OIL AND GAS CONSERVATION COMMISSION / j ¡ I ! FRANK H. MURKOWSKI, GOVERNOR 333 W. pH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Paul Figel Engineering Manager XTO Energy Inc. 200 N. Loraine, Suite 800 Midland, Texas 79701 Re: Middle Ground Shoal C42-23 Sundry Number: 305-050 Dear Mr. Figel: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a iday or weekend. A person may not 'appeal a Commission decision tt]sun n,'or 0 unless rehearing has been requested. (Í ncer, I j , J . orm~ hairman DATED this¡$ day of February, 2005 Encl. SGANNEI~ MAR 0 2 2005 t(t9 '\, b XTO Energy Inc. 200 North Loraine Suite 800 Midland, Texas 79701 432-682-8873 432-687-0862 (Fax) February 21,2005 Alaska Oil and Gas Conservation Commission Attn: Mr. John Norman 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 RE: Request Sundry Approval: Well C42-23 Dear Mr. Norman, XTO Energy, Inc. hereby submits its Application for Sundry Approval to recomplete well C42-23 on Platform C, in the Middle Ground Shoal Field of Cook Inlet, AK. This workover entails the following: 1) Cement squeezing the unproductive GR-GS perforations. 2) Stimulating the HN & HR perforations. 3) Setting a new gas lift string that has straddle packers over the HK interval. Please find attached the following information for your files: A. Form 10-403 Application for Sundry Approval B. Job Procedure c. Present Wellbore Schematic D. Proposed Wellbore Schematic If you have any questions or require additional information, please contact me at (432) 620-6743. Sincerely, Paul L. Figel Engineering Manager Cc: Scott Griffith Tim Smith STATE OF ALASKA AL lA Oil AND GAS CONSERVATION COM¡., JSiON APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 Operational shutdown U Plug Perforations 0 Perforate New Pool D 4. Current Well Class: Abandon U Alter casing D Change approved program D 2. Operator Name: XTO Energy Inc. 3. Address: 1. Type of Request: 200 N. Loraine, Suite 800, Midland, Texas 79701 7. KB Elevation (ft): 35' 8. Property Designation: ADL 18756 11. Total Depth MD (ft): 9850' Casing Structural Conductor Surface Intermediate 2578' 8822' Production Liner 1224' Perforation Depth MD (ft): 9667' Packers and SSSV Type: Total Depth TVD (ft): 9306' Length Suspend U Repair well D Pull Tubing 0 Perforate U WaiverU Stimulate 0 Time Extension D Re-enter Suspended Well D 5. Permit to Drill Number: OtherU Development Stratigraphic 0 D Exploratory D 178-0240 D 6. API Number: 50-733-20315 Service 9. Well Name and Number: C42-23 10. Field/Pools(s): Middle Ground Shoal PRESENT WELL CONDITION SUMMARY Effective Depth MD (ft): Effective Depth TVD (ft): 9753' 9161' Plugs (measured): N/A Junk (measured): N/A Size MD TVD Collapse Burst 13-3/8" 2578' 2492' 2730 psi 1130 psi 7 -5/8" 8822' 8346' 4790 psi 6890 psi 5-1/2" 9848' 9304' 7740 psi 6280 psi Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 9134' 3-1/2",9.2# N80 8628' Guiberson Uni Pkr 7 Packers and SSSV MD (ft): 8575' 12. Attachments: Description Summary of Proposal ~ Detailed Operations Program D BOP Sketch D 14. Estimated Date for Commencing Operations: 16. Verbal Approval: 4/11/05 Date: 13. Well Class after proposed work: Exploratory D Development 15. Well Status after proposed work: Oil 0 Gas D WAG D GINJ D Abandoned WDSPL D D Service D 0 D D Plugged WINJ Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Printed Name.., Paul Figel Title Engineering Manager Signature Paul Figel Phone 432-620-6743 COMMISSION USE ONLY Date 2/21/2005 Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 305------ 0...')"0 Plug Integrity D Other: BOP Test '~ Form 10-403 Revised 11/2004 Mechanical Integrity Test D D Location Clearance '~ COMMISSIONER APPROVED BY THE COMMISSION Date: ){TO RNERGY XTO ENERGY INCg MGS C42-23 COOK INLET, ALASKA STIMULATION & NEW COMPLETION PROCEDURE WELL DATA: SURFACE CASING: 13-3/8" 54.5,61# K55. Set @ 2,578'. Cmt wi 2,100 sx. INTERMEDIATE CASING: 7-5/8" 29.7, 33.7#, N80. Set @ 8,822'. Cmt wi 450 sx. PRODUCTION LINER: 5-~" 17#, N80, @ 8,624 - 9,848'. Cmt wi 210 sx. Sqz liner top wi 150 sx. TUBING: 3-~" 9.2#, N80, 61 Jts 8R, 222 Jts BTC @ 8,629'. KB: 35' PACKER: 7-5/8" Guiberson Uni-Packer vn @ 8,575'. Set in June 1978. PERFORATIONS: GR-GS: 8,654' & 8,689' (2 holes) HK-HN: 9,196 - 9,215' & 9,260 - 9,332' HN-HR: 9,367 - 9,503' HR-HZ: 9,527 - 9,603' & 9,604 - 9,667' NET PAY: 256' BRST: 160 Deg F BHP: 5,000 psi SMALLEST ID: X Nipples: 2.75" ill @ 8,585' & 8,617' MAX DEVIATION: 26 Degrees PRESENT STATUS: Prod @ 30 BOPD, 474 BWPD & 52 MCF as of2-8-05 OBJECTIVE: Cement squeeze the unproductive test perfs in the GR-GS. Stimulate the HN & HR intervals. Install straddle packers over the HK interval wi a Sliding Sleeve in between pkrs. Install a new gas lift string. NOTES: . A production log ran in Oct 2004 showed that the maj ority of the production was coming from the lower HK interval & little inflow from the HN & HR. The last well test prior to the prod log "was 45 BO, 700 BW & 86 MCF. The well is gas lifting on valve #3 of 7 due to the high amount of water & long GLM spacing. Straddle packers & a sliding sleeve win be set over the HK to see the production differences of producing the HN & HR separately from the HK. . BJ to obtain fresh water & oil samples for compatibility testing for Cement & Acid. «I» Leave 1,500~ 2-7/8" 10.4# X95 & 9,000' 14# S135 pipe in for the Procedure 2-18-05 XTO Energy Ince MGS C42-23 Cook Inlet, Alaska 2 ,Materials Required: Weatherford: GI 9,000' 3-1/2" 12.95# PlIO WTS6 tbg for acid frac . 1,500' 2-7/8" 7.9# PlIO WTS6 tbg for acid frac Baker Oil Tools: CD 5-1/2" 17# CIBP - to be WL set . 2 ea 5-1/2" 17# Retrievamatic Pkrs (1 stand-by) 0) 7-5/8" 33.7# Retrievamatic Pkr . 5-1/2" Model F Permanent Pkr - Completion - to be WL set . 5-1/2" Model SABL-3 Permanent Pkr - Completion CD 2- 7/8" Sliding Sleeve MI Drilling Fluids: .. 600 Ibs Soda Ash . 35,000 Ibs KCL (3% KCL FIW = 1,000 Ibs KCL I 100 bbl FIW) Co) 450 lbs Flo- Vis (150 bbl = 3 Ibs I bbl + 5 gal I 100 bbl Greencide) . 45,000 Ibs CaCl2 (Do NOT send out unless reqd as per Step #3 but have on standby) R&K: . 1 ea 500 bbl horizontal frac tank wi steam lines for slick water . 1 ea 150 bbl minimum capacity plastic lined tank for 5,000 gal acid PTS: . 250 bbl Test Tank BJ Services: . 70 sk Class G Cement + Adds 4» Chemicals for 20,000 gal Slick water . 5,000 gall 0% HCL Acid wi 25% xylene . 700 gall 0% Pickle Acid . Tbg annulus Pop-off valve . WH connection: X-Over for 3-1/2" WTS6 Box Pollard: . 11 - 3-1/2" GLM's . 3 - 2-7/8" slimhole GLM's (1 GLM to contain an equalizing valve) Mise: . Bits & scrapers for both 5-1/2" 17# & 7-5/8" 33.7# Csg . 3000 # Wax Pellets (Astor Corp) Procedure 2-18-05 XTO Energy Inc@ MGS C42-23 Cook Inlet, Alaska 3 Procedure: 1. SD gas lift. Bleed-off press. MIRU slickline unit. Press test lubricator to 1,000 psi. RIH wi 2.65" gauge ring to check for scale & fill. 2. RIH wi pulling tool to GLM #7 @ 8561'. POOH wi orifice valve. RD SL unit. 3. MIRU derrick over wellhead. Ifwell does NOT flow, prep 450 bb13% KCL (1,000 Ibs KCL I 100 bbl FIW) in pits. Contingeny Plan to kill weU: Weight up to 9.6 ppg 22% KCL (88 #/bbl) & CaCI2 for additional weight above 9.6 ppg. 4. Kill well by circ 3% KCL down the tbg. 5. Notify the AOGCC 24 hrs prior to the BOP test. Set BPV's & ND WHo Install riser & NU BOP's. Pull BPV's & set double check valves. Press test BOP's to 5,000 psi. 6. RU Weatherford tong services. Attempt to pull the 3-1/2" tbg & release the 7-5/8" Guiberson retrievable packer @ 8,575'. Max pull @ 80% is 166,000#. POOH & LD tbg while checking for NORM. Send GLM's to Pollard WL. Send tbg to Weatherford to be sold for scrap. Contingenv Plan if packer fails to release: a. MIRU APRS WL. RIH wi jet cutter & cut tbg below last co!lar above the packer. RD APRS. POOH wi tbg. b. MU Baker Fishing Overshot BHA. RIH with overshot on 9 drill collars & 4" DP. Jar packer free. POOH. LD pkr & tailpipe. c. Mill out packer as last resort if packer does not release. 7. RIH wi 4-1/2" bit, 1 st scraper for 5-1/2" 17#,6 jts of2-7/8" DP & 2nd scraper for 7-5/8" 33.7# csg on 4" DP. Run top scraper down to TOL @ 8,624'. Rev circ hole clean wi a 20 bbl Flo-visc pill (3 lbs per bbl + 5 gal/1 00 bbl Greencide). POOH. LD bit & both scrapers. CEMENT SQUEEZE THE GR-GS PERFS: 8. RU APRS e-line unit wi eCL. RIH wi Baker 5-1/2" 17# CIBP & set @ 8720'. (Note Csg collars @ 8,700' & 8,741'.) POOH. Leave WL unit on board for Step #29. 9. PU & RIH 7-5/8" 33.7# Retrievamatic packer + 3 jts 2-7/8" tailpipe wi muleshoe. Set packer wi tailpipe @ 8,450'. Test backside to 500 psi. 10. MIRU BJ cement unit & batch mixer. Have the 700 gall 0% HCL Pickle acid on lac that will be used in Step #23. Press test lines to 6,000 psi. Put 500 psi on backside. Est inj rate into GR-GS perfs @ 8,654 & 8,689' with:1: 20 bbl 3% KCL @ 4,000 psi @ 1,2, & 3 BPM. Record the press @ each rate. Raise press limit to 5,000 psi if no inj rate. If the perfs do not break do\vn, release the packer. Run tailpipe down to 8,700'. Balance & spot 4 bbllO% BCL from 8,700 - 8,575'. PUR wi tailpipe to 8,450'. Set packer. Put 500 psi on backside. Est inj rate & overflush acid by 50 3% IZCL. Procedure 2-18-05 XTO Energy IncQ MGS C42-23 Cook Inlet, Alaska 4 11. Batch mix 70 sk Class G + FLAC + Dispersant + Retarder @ 15.8 ppg, Yield = 1.15 cuft/sk. (Cmt slurry to have :f: 150 cc fluid loss & thickening time of 3 hrs.) 12. Unset packer. Break circ wi 3% KCL. Pump 10 bbl fresh water ahead. Pump 14 bbl cement slurry. Pump 10 bbl fresh water. Displace wi 3% KCL water. Set the packer with the cement 15 bbl above the packer. Displace cmt 1 bbl below the EOT. Cant pumping if getting a running sqz, otherwise, shutdown for 15 min. Hesitate in 2 bbl slurry in 'l1 bbl increments while SD 15 minutes between each hesitation. Do NOT displace emt past 8,550'. Max sqz press = 5,000 psi. 13. Release pkr. Reverse out DP by 1.5 times wi 3% KCL water @ 3-4 BPM. Reset packer. Press up sqz to 500 psi. (LEAVE 81 IF WELL IS ON VACUUM.) RD BJ. Hold cmt unit for Step #16. 14. woe for 8 hrs. POOH & LD pkr. 15. PU & RIB wi bit for 7-5/8" 33.7# csg. Drill out cmt to TOL @ 8,624'. POOH. LD 7" bit. 16. PU & RIH wi bit for 5-1/2" 17# csg. Drill out cmt to 8,670'. Press test sqz hole @ 8,654' wi 1,000 psi. Cant drilling until falling out of cmt. Press test sqz to 1,000 psi. Contact the Midland office if the press test fails. Otherwise, drill out the CIBP @ 8,720'. Circ a 20 bbl gel sweep. POOH & LD bit. Release the BJ Cement Equip. STIMULATE THE fiN & HRINTERVALS: 17. RIH wi bit & scraper for the 5-1/2" 17# csg on 2-7/8" & 4" DP. Cleanout to PBTD @ 9,753'. Rev circ hole clean wi 20 bbl Flo-visc pill. POOH. LD 2-7/8" & 4" DP. Send to onshore. 18. MI frac string: 9,000' of3-1I2" 12.95# PlIO WTS6 tbg & 1,500' 2-7/8" 7.9# PlIO WTS6 tbg. 19. Once the pipe deck is clear, spot 1 ea 500 bbl frac tank, 1 plastic coated acid tank (150 bbl minimum capacity) & 250 bbl PTS flowback tanle Fill the frac tank wi 475 bbl 3% FIW. Attach steam lines & heat the FIW to 80°F. 20. MU Baker 5-1/2" Retrievamatic packer + 1 jt tailpipe. RIB & set packer between the HK & HN perfs @ :f:9,345'. (Collar is @ 9,354'.) Slackoff20K. RU mud pump on tbg. Check backside for communication by pumping 30/0 KCL down the workstring @ 1-2 BPM @ 1,000 psi MAX. Move packer if necessary. (The mud pump will pump 3% KCL down the backside during the frac job in case the HK communicates during the job.) 21. MIRU BJ Frac equipment: 2 frac pumps & blender. lit RU XTO line from rig floor to PTS flowback tank. (Pickle job) . Install 2 pressure transducers on treating line & 1 on tbg annulus. 41) Install Pop-off valve on tbg annulus set @ 1,000 psi. 700 gall 0% HCL Pickle Acid to contain: II 2 gpt CI-25 Corrosion Inhibitor . 2 gpt NEI18 Non-emulsifier Procedure 2-18-05 XTO Energy Inco MGS C42-23 Cook Inlet, Alaska 5 5,000 gal Frac Acid System to contain (to be tested wi oil sample): e 10% HCL . 250 gpt Xylene @ 1 gpt FR W -14 Friction Reducer fg 2 gpt CI-25 Corrosion Inhibitor fþ 7 ppt F200 Iron Reducing Agent . 30 ppt F300 Iron Chelating Agent . 3 gpt Claytreat 3C It 2 gpt NEll8 Non-emulsifier . 3 gpt S400 Surfactant 475 BBL Slick Water contain: .. 3% KCL . 0.4 ppt X-cide-207 Bacteriacide . 25 gpt GW-27 Gelling Agent . 2 gpt NE-118 Non-emulsifier .:. Diverting Agent: 3000# Wax Pellets (melting point @ 120-130 deg F) 22. Press test lines to 9,000 psi. MAX PRESS for frac is 8.,000 psi. 23. Release pkr. Pickle the tbg with 500 (or 700) gal 10% HCL. Underdisplace the add by 500' from the end of tbg. Reverse acid wi mud pump to the 250 bbl test tank. Have 600# soda ash in the test tank before acid is circ into the test tanle Pump returns into disposal well C44-14RD. Reset pIa. 24. Prac the HN perfs @ 9,367 -9,503' & HR perfs @ 9,527 -9,667 @ 10 BPM wi 5,000 gall 0% acid & 475 bbl slick water according to the following schedule. Mud pump will pump 3% KCL down the tbg annulus into the HK during the job, maintaining a max press of 900 psi. STG FLUID 1 ACID Vol WATER Vol CUMM I Divertor I (BBl) (BBl) (BBL) (lbs) I 1 Acid 24 24 2 SLK WTR 80 104 200 3 Acid 24 128 4 SLK WTR 90 218 300 5 Acid 24 242 6 SLK WTR 90 332 400 7 Acid 24 356 8 SLK WTR 90 446 500 9 Acid 24 470 10 SLK WTR, 125 595 TOTALS: 120 475 1400 Drop the divertor (Wax Pellets) @ the start of the slick water stages. Incr or decr the amount based on the pressure responses. 25. Overflush last acid stage with 125 bbl slick water. SD. Obtain ISIP, 5, 10, & 15 minute readings. RD frac equipment. Procedure 2-18-05 XTO Energy lucs MGS C42-23 Cook Inlet, Alaska 6 26. Flow well back to the PTS tank to recover load. Record volume being pumped down disposal well. 27. Release the pIa. I(ill well if necessary with weighted KCL water. POOH. LD 3-1/2" & 2-7/8" WS. 28. MI 8,900' of 3-112" 9.3# L80 8rd EVE tbg (incl5% excess) & 900' 2-7/8" 6.5# L8D 8rd EVE. 29. RU APRS E-line unit wi CCL. RV Baker E-4 Setting Tool & adapter kit. RIH & set the lower Model F permanent packer on WL @ 9,342'. (Note Csg collar @ 9,314 & 9,354'.) POOH wi setting tooL RD & release APRS equipment. Item I Length, ft Top Bottom Baker 5-1/2" Model F Perm Pkr (45-30) 3 9,342 9,345 Baker Seal bore Extension 5 9,345 9,350 X-over Acme Box to 2-7/8" 6.5# 8rd Pin 1 9,350 9,351 6' Pup Jt, 2-7/8" 6.5# L80 8rd EUE 6 9,351 9,357 2-7/8" XN Nipple (2.205" ID) 9Cr 1 9,357 9,358 4' Pup Jt, 2-7/8" 6.5# LBO 8rd EUE 4 9,358 9,362 WL REG 1 9,362 9,363 30. RIH wi top Baker SABL-3 permanent packer & GLM's on 2-7/8" & 3-1/2" tbg as follows: Item ! length, ft Top I. Bottom 3-1/2" 9.3# L80 8rd EUE 300 0 300 6' Pup Jt, 3-1/2" 9.3# L80 8rd EUE 6 300 306 Baker TE5 SSSV (2.81" ID) 5 306 311 4' Pup Jt, 3-1/2" 9.3# L80 8rd EUE 4 311 315 3-1/2" 9.3# L80 8rd EUE 8,209 315 8,524 X-over 3-1/2" 9.3# 8rd Box X 2-7/8" 6.5# 8rd Pin 1 8,524 8,525 2-7/8" 6.5# L80 8rd EUE tbg 639 8,525 9,164 2-7/8" X Nipple (2.313" 10) 9Cr 1 9,164 9,165 6' Pup Jt, 2-7/8" 6.5# L80 8rd EUE 6 9,165 9,171 Anchor 1 9,171 9,172 Baker 5-1/2" Model SABL-3 Perm Pkr 3 9,172 9,175 6' Millout Extension 6 9,175 9,181 X-over MOE Box to 2-7/8" 8rd Pin 1 9,181 9,182 2 Jts 2-7/8" 6.5# L80 8rd EUE tbg ** 64 9,182 9,246 5' Pup Jt, 2-7/8" 6.5# L80 8rd EUE 5 9,246 9,251 2-7/8" GLM wi Equalizing Valve 7 9,251 9,258 6' Pup Jt, 2-7/8" 6.5# L80 8rd EUE I 6 9,258 9,264 Baker 2-7/8" S Sleeve wi 2.313" 10 profile. RHC plug! 5 9,264 9,269 body to be installed. SS in closed position. 2 Jts 2-7/8" 6.5# L80 8rd EUE tbg ** 64 9,269 9,333 8' Pup Jt, 2-7/8" 6.5# L80 8rd EUE 8 9,333 9,341 Locator wi 7' Bonded Seals 1 9,341 9,342 ** Use 4 jts of tbg that are :1::32' for spacing b/w packers. Procedure 2-18-05 XTO Energy Ince MGS C42-23 Cook Inlet, Alaska 7 Gas lift mandrels spaced as follows (Bottom GLM should be at least 1 jt above the X nipple @ :f:9,164'): GAS LIFT DESIGN GLM #1 #2 #3 #4 #5 #6 #7 #8 #9 #10 #11 #12 #13 MD 1883 3130 4229 5083 5608 6080 6559 7035 7510 7984 8355 8775 9146 TVD , PORT 1850 1 0 3000 12 4000 12 4800 ~ 16 5300 I 16 5750 16 6200 16 6650 16 7100 16 7550 16 7900 16 8300 , 20 8650 24 PSC 920 910 900 890 880 870 860 850 840 830 820 810 I ORIFICE GLM's 1-11 are 3-1/2" & GLM's 12 & 13 are 2-7/8" PSO 955 954 934 931 915 905 893 883 872 855 844 838 31. Locate bottom packer & space out. PUR 5'. Mix up 20 bbl biocide pill to contain 4 gal Nalco EC1124A Packer fluid + 10 gal Nalco 99VD-049 Biocide in 20 bbl FIW. Circ pin down tbg wi brine. Under-displace pill by 10 bbl inside the tbg. 32. Land tbg. Drop ball-rod assembly. Press test tbg to 1,000 psi for 10 min. Cont to press up to 3,000 psi to set packer. 33. Set BPV. ND BOP's. NU WHo Set db I check valve & test WH to 5,000 psi. Pull out dbl ck. Release Rig. 34. MIRU XTO slickline unit & lubricator. RIH wi JDC pulling tool to :f:9,240'. Latch & POOH wi ball- rod assembly. RIB wi 2" GS pulling tool to 9,240'. Latch & POOH wi RHC plug. RD WL. 35. Start up gas lift. Test the well for 4-5 days. Record hourly production rates for the first 48 hrs. Record rates every other hour for next 2-3 days. Leave the sliding sleeve closed & produce the HN & HR for at least 1-2 months before discussing opening the SS to the HK. Paul Figel, Engineering Manager Kyle Hammond, Vice President Operations, Alaska Procedure 2-18-05 )tt9 MGS C42-23 Cook Inlet, Alaska leg 4, Conductor 25 API No.: 50-133-20315 Spud: 3-13-78 Surf Csg: 13 3/8", 54.5/61 Ib, K55. Set @ 2,578'. Cmt w/2, 100 sx. Intermediate Csg: 7 5/8" 29.7/33.7 Ib, N80. Set @ 8,822'. Cmt w/450 sx. TOe @ :1:6,642'. Prod Liner: 5-1/2", 17 Ib, N80. Set @ 9,848'. TOL @ 8,624'. Cmt w/210 sx. Sqz TaL w/150 sx. FILL: None (6-4-04) PBTD: 9,753' MD (9,161' TVD) TO: 9,850' MO (9,306' TVO) Present Completion n II mI ~ ~ ~ ~ ~ ~ ~ ~ J J J J J J KB: 35' Water Depth: 73' MSL PLF 2-15-05 Tubing: 3 1/2", 9.2#, N80 @ 8,629'. 61 Jts 8R, 222 Jts BTC. Set 6-7-78 Item MD GLM 1 2033 GLM 2 3907 GLM 3 5438 GLM 4 6628 GLM 5 7596 GLM 6 8314 GLM 7 8561 TVD 1989 3707 5138 6272 7180 7862 8095 ptro Port 935 3/16" 925 3/16" Orifice 5/16" Dummy N/A 935 1/4" 920 1/4" 955 5/16" Ball Valve @ 300' Guiberson Uni-Packer VII @ 8,575' Otis "X" Nipple (2.75" 10) @ 8,585' Otis "X" Nipple (2.75" 10) @ 8,617' Mule-shoe @ 8,628' Note: EOT is 5' inside 5-1/2" liner. J >-< r( D ~ GR-GS: 8,654' & 8,689' (2 holes) HK-HN: 9,196'-9,215' HK-HN: 9,260'-9,332' HN-HR: 9,367'-9,503' HR-HZ: 9,527'-9,603' HR-HZ: 9,604'-9,667' Ji!R MGS C42-23 Cook Inlet, Alaska Leg 4, Conductor 25 API No.: 50-133-20315 Spud: 3-13-78 Surf Csg: 13 3/8", 54.5/61 Ib, K55. Set @ 2,578'. Cmt wi 2,100 sx. Intermediate Csg: 7 5/8" 29.7/33.7 Ib, N80. Set @ 8,822', Gmt wi 450 sx. TOC @ :!:6,642'. Prod Liner: 5-1/2", 17 Ib, N80. Set @ 9,848'. TOl @ 8,624'. Gmt wi 210 sx. Sqz TOl wi 150 sx. GLM #1 #2 #3 #4 #5 #6 #7 #8 #9 #10 #11 #12 #13 PORT 10 12 12 16 16 16 16 16 16 16 16 20 24 MD 1883 3130 4229 5083 5608 6080 6559 7035 7510 7984 8355 8775 9146 TVD 1850 3000 4000 4800 5300 5750 6200 6650 7100 7550 7900 8300 8650 FILL: None (6-4-04) PBTD: 9,753' MD (9,161' TVD) TO: 9,850' MD (9,306' TVO) PSC 920 910 900 890 880 870 860 850 840 830 820 810 ORIFICE pso 955 954 934 931 915 905 893 883 872 855 844 838 Proposed Com pletion ~ J~ ~ ! ;~ I I ~ u J -.J i ~ I .J .J .J \ / .J % ~ ~ J~ ~ ~. rá ~ Z?d ;a- --- ~ JITf ~ ~ ;:;;r: ~Z Z~ ~ J\ ~ ~ ~ W- --.-,.,--- PLF 2-18-05 KB: 35' Water Depth: 73' MSL Tbg: 3-%" 9.3# L80 8rd EUE surf - 8,524' 2-7/8" 6.5# L80 8rd EUE 8,524 - 9,363'. Set: 3-%" Baker TE5 SSSV (2.81" ID) @ 306' X-over 3-%" 9.3# 8rd to 2-7/8" 6.5# L80 8rd @ 8,524' 2-7/8" X Nipple (2.313" 10) 9Cr @ 9,164' 6' Pup Jt, 2-7/8" 6.5# L80 8rd EUE @ 9,165' Anchor @ 9,171' Baker 5-%" SABL-3 Perm Packer @ 9,172' 6' Mil/out Extension @ 9,175' X-over MOE Box X 2-7/8" 6.5# 8rd Pin @ 9,181' 2 Jts tbg 2-7/8" 6.5# L80 8rd EUE @ 9,182' 5' Pup Jt, 2-7/8" 6.5# L80 8rd EUE @ 9,246' 2-7/8" GLM wI Equalizing Valve @ 9,251' 6' Pup Jt, 2-7/8" 6.5# L80 8rd EUE @ 9,258' Baker 2-7/8" CMU Sliding Sleeve (2.313" 10) @ 9,264' 2 Jts tbg 2-7/8" 6.5# L80 8rd EUE @ 9,269' 8' Pup Jt, 2-7/8" 6.5# L80 8rd EUE @ 9,333' Baker Locator wI 7' Bonded Seals @ 9,341' Baker 5-%" Model F Perm Packer (45-30) @ 9,342' Baker 5' SBE @ 9,345' X-Over Acme Box X 2-7/8" 6.5# 8rd Pin @ 9,350' 6' Pup Jt, 2-7/8" 6.5# L80 8rd EUE @ 9,351' 2-7/8" XN Nipple (2.205" 10) 9Cr @ 9,357' 4' Pup Jt, 2-7/8" 6.5# L80 8rd EUE @ 9,358' WLREG @ 9,363' GR-GS: 8,654' & 8,689' (2 holes) SQZ'd wi 70 sk. HK-HN: 9,196'-9,215' HK-HN: 9,260'-9,332' HN-HR: 9,367'-9,503' HR-HZ: 9,527'-9,603' HR-HZ: 9,604'-9,667' XTO Energy Inc. 3000 North Garfield Suite 175 Midland, Texas 79705 432-682-8873 432-687-0862 (Fax) September 26, 2003 Alaska Oil and Gas Conservation Commission Attn: Mr. Randy Ruedrich 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 RE: Report of Sundry Well Operations: Well C42-23 Dear Mr. Ruedrich, XTO Energy, Inc. hereby submits the Report of Sundry Well Operations (Form 10-404) for the Coil Tubing acid stimulation performed on C42-23 on Platform C in the Middle Ground Shoal Field of Cook Inlet, Alaska. Please find attached the following information for your files: 1. Form 10-404 2. Daily Operations Reports If you have any questions or require additional information, please contact me at (432) 620-6743. Sincerely, Paul L. Figel Sr. Production Engineer Cc: Doug Marshall Tim Smith ORIGINAL i STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate Pull tubing After casing Plugging Perforate Repair well. Other 2. Name of Operator 3. Address 3000 N. Garfield, Ste 175, Midlar~, TX 79705 5. Type of Well: Development x Exploratory Stratigraphic Service 4. Location of well at surface Platform C, Leg 4, Conductor 25, 509' FSL & 1541' FE~ of Sec. 23, T8N, R13W, SM At top of productive interval 8654', 3043' FSL & 1882' FEL of Sec. 23, TSN, R13W, SM At effective depth At total depth 9850', 3455' FSL & 1941' FEL of Sec. 23, TSN, R13W, SM 6. Datum elevation (DF or KB) 116' IF 7. Unit or Property name 8. Well number C42-23 feet 9. /P,.e,rmit_n.u_.mber/approval number ~1~'"~~/301_307 10. APl nu~n~, 50-7/~X3_2o315 11. Field/Pool M~S/"F" & "G" Pools 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural Conductor Surface 2578' Intermediate 8822 ' Production 1224' Liner Perforation depth · measured 9850' feet Plugs (measured) 9306' feet 9753' feet Junk (measured) 9161' feet Size Cemented 13-3/8", 54.5-61#, K55 7-5/8", 29.7-33.7%, N8 0 5-1/2", 17%, N80 Measured depth True vertical depth 2100SX 2578' 2492' 450SX 8822' 8346' 210SX 8624-9848' 8158-9304' 8654-9667' truevertical 8221'-9134' Tubing (size, grade, and measured depth) . 3-1/2", 9.3~. N-80 @ 8629' Packers and SSSV (type and measured-depth) 6~,~herscn %%~i-packer VII ~ 8575' 13. Stimulation or cement squeeze summary ~K-~N, ~]N-~'~ & ~']R-~ Intervals treated (measured) 9196-9667' Treatmentdescriptionincludingvolumesused andfinalpressure Ooil tbgacid/~j'leae~a..~az~~ze w/10,000 ga].. AVGWHP = 3400 psi. 14. Prior to well operation 12 Subsequent to operation 83 Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure 23 12 450 65 132 953 870 60 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil X Gas___ Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed 9~J' ~ Form 10-404 Rev 06/15/88 OCT 0 Paul L. Figel Title Sr. Productica% Engineer ORI-G-INAL Date 9/26/03 SUBMIT IN DUPLICATE XTO ENERGY INC. Well: MGS C42-23 Objective: Coil Tbg Acid Stimulation Pre-Job Production: 12 BOPD, 12 BWPD, 23 mcf/d Date: 8-18-03 Offioaded BJ coil tbg equipment and acid on to Platform. Start RU equipment. Date: 8-19-03 Completed RU equipment & mixing up acid. Pickled coil tbg with 6 bbl 10% HCL. Flushed reel with 50 bbl FIW to Flowback tank. Press tested BOP's to 500 psi & 5,000 psi. Good tests on the pipe rams and backup pipe rams. Had trouble getting test on blind rams. Repaired valve and got good test on blind rams. Break out injector head. MU Rotojet hydraulic jetting tool. MU lubricator. Stab CT injector. Press tested lubricator to 500 & 5,000 psi. Found leak on suction manifold on triplex pump. Welder tried to repair leaks but manifold was eroded beyond repair. BJ has new sump manifold coming out on morning chopper in 8 hrs. Decided to continue with job hydroblasting the production tbg with water while waiting on parts. Date: 8-20-03 Began RIH @ 60 fpm, pumping slick 3% KCL FIW @ 1 BPM with pump press @ 2,100 psi. Slowed coil rate to 10 fpm while passing over the 7 GLM's. Washed 3-1/2" production tbg with 6 bbl xylene/10% HCL acid from 8,500 -8,630'. Cont'd DH and tagged bottom @ 9,744'. Circ 20 bbl gel pill to surface. Pull up hole while spotting 24 bbl 10% acid from 9,700 - 8,650'. PU to 8,550'. SD and let acid soak for 30 min. RIH while circ out acid pill with 3% KCL FIW to flowback tank. Washed perf's from 9,196- 9,667' with 52 bbl xylene/10% HCL while making 2 passes with coil tbg. Set coil tbg @ 9,680' and circ out acid with a 20 bbl gel pill followed with 3% KCL FIW. Closed in coil tbg annulus. Start acid squeeze w/156 bbl xylene/10% HCL + 200 gal Ondeo Nalco EC6085 Scale Inhibitor across perfs 9,680 - 9,180'. Made 6 passes with avg WHP = 3400 psi and pump press = 4,500 psi with injection rate @ 0.5 to 0.75 BPM. Started over-flush of acid w/3% KCL FIW @ midnight. Date: 8-21-03 Overflushed acid with 160 bbl 3% KCL FIW @ 0.9 BPM with pump press @ 4,800 psi and WHP @ 2,650 psi. Made 4 passes over perfs from 9,680 -9,180' @ 10 fpm while over-flushing. PUH to 9,100'. Opened coil annulus and started POOH while circ 3% KCL FIW @ 0.3 BPM. Coil tbg to surface. SI swab valve. Bleed-off press. Job complete at 0700 hrs. RD coil tbg injector head, lubricator and riser. Moved coil tbg equipment over to well C22-23. Opened well to gas lift at 1530 hrs. Got acid returns in flowline. SD gas lift and SI well. RU flowline to flowback tank to take returns until pH is neutral. RU gas vent line to header system. Started up gas lift @ 1730 hrs. Well flowing @ _+50 bbl/hr with oil sheen into flowback tank. Recovered 225 bbl in 4.5 hrs. Started pumping load in test tank to disposal well. Moved well production from flowback tank to main production header at midnight with +/- 325 bbl load recovered in 6.5 hrs. Date: 8-22-03 Put well in test @ 1000 hrs. Had recovered _+ 825 bbl load before going into test. RATE Water FLUID CUM EQUIV EQUIV TBG CSG GAS TIME BPH Cut,% BPD TOTAL BOPD BWPD PSI PSI INJ Comments 825 Recovered 825 bbl before test 1000 32.0 94.0 768 825 46 722 90 920 1036 StartTest 1100 36.0 94.0 864 861 52! 812 90 900 1139 1200 48.0 94.0 1152 909 69 1083 90 900 1243 1300 50.0 94.0 1200 959 7~, 1128 90 900 1243 1400 40.0 94.0. 960 999 58 902 90 900 1243 1500 42.0 94.0 1008 1041 60 948 90 900 1243 1600 39.0 94.0 936 1080 56 880 90 900 1243 1700 40.0 94.0 960 1120 58 902 90 900 1243 1800 39.0 94.0 936 1159 56 880 90 900 1243 Date: 8-23-'03 Cont'd well test. IDA crew offioading coil tbg equipment to boat. Date: 8-24-03 Cont'd well test. Date: 8-25-03 Cont'd well test. Date: 8-27-03 Well test: 83 BOPD, 953 BWPD. Injecting 1319 mscf/d. Casing press @ 860 psi & WHP @ 60 psi. Re: Reactivate Sundry Approval # 301-307 for C42-23 Subject: Re: Reactivate Sundry Approval # 301-307 for C42-23 Date: Wed, 06 Aug 2003 10:56:40 -0800 From: Tom Maunder <tom_maunder@admin.state.ak.us> To: Paul_Figel@xtoenergy.com Hi Paul, We have been looking at how long a sundry is "good for". That said, what may come to pass is that sundries are good for 2 years just like drilling permits. With your message, you have done what I think should be done to an approval that is a little out of date. Based on the provided information, a new sundry should not be needed. I will place a copy of this message and your attachments in the well file. Good luck with the work. Any further information on the stimulation you did in mid July on C?? Tom Maunder, PE AOGCC Paul_Figel@xtoenergy.com wrote: I had submitted a 10-403 for the C42-23 Coil Tbg acid job back in Oct 2001 & it was approved on 1 t-6-2001 with Permit #301-307. We never did do the treatment as it was too cold in November & December. The job got pushed back again since we moved drilling from Platform A to C in Jan 2002. Well, now we want to do this job on the C42-23. Do I need to submit another 403 or is the old still good to go? I did revise the procedure since then, which I have attached. I am waiting to hear from BJ when they will have a crew but am aiming for Aug 20th or 26th for the start date. Let me know if you require any more info. Thanks, Paul (See attached file: C42-23 CT Acid Procedure 8-6-03. doc)(See attached file: C42-23 Schematic 7-29-03. doc) > Name: C42-23 CTAcid Procedure 8-6-03. doc > C42-23 CTAcid Procedure 8-6-03. doc Type: WINWORD File (application/msword) > Encoding: base64 > > Name: C42-23 schematic 7-29-03. doc > C42-23 Schematic 7-29-03. doc Type: WINWORD File (application/msword) > Encoding: base64 Tom Maunder <tom maunderC, admin.state.ak.us> sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission I of 1 8/6/2003 10:57 AM XTO Energy Inc. MGS C42-23 COOK INLET, ALASKA COIL TBG CLEANOUT AND ACID STIMULATION PROCEDURE WELL DATA: SURFACE CASING: 13 3/8" 54.5, 61# K55. Set ~ 2,578'. Cmt w/2,100 sx. INTERMEDIATE CASING: 7 5/8" 29.7, 33.7#, N80. Set ~ 8,822'. Cmt w/450 sx. PRODUCTION LINER: 5 ½" 17#, N80, ~ 8,624 - 9,848'. Cmt w/210 sx. Sqz liner top w/150 sx. TUBING: 3 ½" 9.2#, N80, 61 Jts 8R, 222 Jts BTC PACKER: 7 5/8" Guiberson Uni-Packer VII ~ 8,575'. Set in June 1978. PERFORATIONS: GR-GS: 8,675 & 8,679' (2 holes) HK-HN: 9,196- 9,215' HK-HN: 9,260 - 9,332' HN-HR: 9,367- 9,503' HR-HZ: 9,527- 9,603' HR-HZ: 9,604- 9,667' NET PAY: 256' BHST: 160 Deg F BHP: 5,000 psi SMALLEST ID: X Nipples: 2.75" ID @ 8,585' & 8,617' PRESENT STATUS: Prod ~ 9 BOPD, 13 BWPD, & 524 mcf/d as of 7-21-03 OBJECTIVE: Coil tbg clean out fill and acid stimulate the HK-HZ. NOTE: The last WL mn on 7-22-03 encountered scale in the 3-1/2" tbg ~ 8,537 - 607' & bridges in the 5-1/2" csg ~ 9,327' & 9,338'. Fill was tagged ~ 9,368'. NO ACID IS TO BE PUMPED INTO THE PRODUCTION HEADER SYSTEM. A 250 BBL FLOWBACK TANK WILL BE USED TO HANDLE ALL ACID RETURNS. Procedure 8-6-03 XTO Energy Inc. MGS C42-23 Cook Inlet, Alaska Prior to the workover, production operator will get 1 qt of oil from offset well C21A-23 for an acid / oil compatibility test. The acid is to contain 1,000 ppm ferric iron (Fe3) for testing. Materials Required: · 10,000 gal (238 bbl)10% One-Shot Plus Acid (25% xylene: 75% - 10% HCL) · 60 bbl Gel Pill (3#/bbl Flo-Visc + 5 gal/100 bbl Greencide provided by MI Drill Fluids) · 900 bbl 3% KCL FIW Water (Friction Reducer Supplied by BJ) ~ 9,000 lbs Powdered KCL (1000 lbs KCL/100 bbl FIW for 3%) · N2 bottles to purge reel after job · 3,000 lbs Soda Ash (Supplied by MI) · Ondeo Nalco EC6085A Scale Inhibitor Equipment Required: · BJ 1%" CTU: Install press gauges on CT, CT annulus and 3 ½" tbg annulus. · 1 ea HP Triplex Pump · RotoJet Tool · Filter Skid (8 micron) · Acid Tank for 250 bbl (Supplied by R&K) · Baker 2-1/8" Mud Motor & Mill on Stand-By · 250 bbl Flowback Tank ~ Mud Pump to be tied into tank to pump load to C44-14RD Disposal Well > Install 2" vent hose on top of tank to vent overboard > Add 3,000# of Soda Ash to tank · Return line w/choke manifold to 250 bbl Surge Tank & to Production Facilities > Manifold to contain a sample catcher to monitor fluids pH > Send "clean" returns to Production Facilities > Send live acid and or fluids containing scale or solids to Flowback Tank · Have a H2S monitor ~ the Flowback Tank Acid System to contain these additives (Conc. dependent on acid / oil compatibility test): · 10% HCL (Acid to be titrated on location.) · 250 gpt Xylene · 5 gpt CI-27 Corrosion Inhibitor · 7 ppt F200 Iron Reducing Agent · 30 ppt F300 Iron Chelating Agent · Surfactant / Dispersing Agent for Xylene · Non-Emulsifier / Anti-Sludge Additive Scale Inhibitor (Ondeo Nalco EC6085A) Procedure 8-6-03 XTO Energy Inc. MGS C42-23 Cook Inlet, Alaska PROCEDURE: SD Gas Lift. MIRU 1.75" Coil tbg unit, riser, BOP's & Injector head. RU filter skid upstream of liP triplex. Contact AOGCC 24 hrs prior to BOP test. Press test BOP's to 5,000 psi. Test treating lines to 6,000 psi. Max press is 5,000 psi. CTU operator to ensure all tools to be calipered before RIH. Smallest ID = 2.75" ~ X Nipples ~ 8,585' & 8,617'. 2. Hold safety meeting with all service & production personnel about the procedure, corrosive chemicals, and possible H2S exposure. PICKLE COIL TBG: 3. Keep the swab valve closed & open kill line on BOP's to the Flowback tank. Pickle the coil tbg with 6 bbl acid. Flush acid with slick 3% KCL FIW. Check for neutral pH. Close valve on manifold to the Flowback tank and open swab valve & wellhead valve to production. CLEAN OUT HOLE: 4. RIH w/Coil tbg ~ 80 fpm while pumping @ 1 BPM slick 3% KCL FIW. Slow rate to 5 fpm when passing over the Gas Lift Mandrels (See Attached WBD) and make 2 passes. Continue to RIH ~ 80 fpm to 8,500' where scale was encountered with WL. o Wash the 3-1/2" Prod tbg from 8,500- 8,629' (EOT) ~ 10 fpm ~ 1.5 BPM w/slick 3% FIW. Use acid only when necessary to get past tight spots. (Divert acid back to Flowback tank when necessary.) 6. Once out of the 3-1/2" Prod Tbg, cont DH ~ 40 fpm to 9,100'. Slow coil tbg to 10 fpm as the jetting tool passes over the perfs from 9,196 to PBTD ~ 9,753'. 7. Tag up ~ PBTD or as deep as possible. Circ hole clean w/20 bbl Flo-Visc pill to surface followed with slick 3% KCL FIW ~ 1.5 BPM. ACID SPOT & SOAK: 8. Pull up to 9,700'. Lay 1,000 gal (24 bbl) 10% acid from 9,700' to 8,650' while pulling up hole using slick 3% KCL FIW to displace. PU CT to 8,550' and SD. Let acid soak for 30 min. , Keeping the CT annulus open, RIH ~ 20 fpm to TD while circ slick 3% KCL FIW to surface ~ 1.5 BPM. Circ hole clean w/10 bbl Flo-Visc pill to surface followed with slick 3% KCL FIW. Send acid returns to the Flowback Tank. ACID WASH PERF'S: 10. Acid wash perf's 9,667- 9,196' w/2,200 gal (52 bbl) 10% Acid ~ 1.5 BPM, moving the Coil tbg 28 ft/min from 9,680- 9,180'. Make 1 pass up and 1 down. 11. RIH to TD. Circ hole clean w/20 bbl Xanthan gel pill to surface followed with slick 3% KCL FIW ~ 1.5 BPM. Do NOT mix any friction reducer to FIW beyond this step. Procedure 8-6-03 XTO Energy Inc. MGS C42-23 Cook Inlet, Alaska ACID INJECTION JOB: 12. Close the Coil tbg annulus. Inject 6,550 gal (156 bbl) 10% acid into the perf's while making 4 passes across the interval from 9,680 - 9,180' while pumping @ 0.75 BPM and moving the Coil Tbg ~ 10 ft/min. 13. Finish pumping all acid @ 9,680'. Over-displace acid by injecting 150 bbl 3% KCL FIW (NO FRICTION REDUCER) @ 0.75 BPM. Make 4 passes from 9,680 - 9,180' ~ 10 ft/min. 14. POOH with coil tbg @ 100 fpm. Close the Swab valve. Bleed off press. 15. RD Coil Tbg Unit. Mud pump to unload Flowback tank to disposal well. Leave Flowback tank rigged up while well is unloading in case live acid is seen at surface. 16. Start up gas lift and put well into test. Monitor the well for +5 days taking readings every hour for first 2 days. Take readings every other hour for 3-5 days. Put well back into regular test rotation after 5 days. Record any use of the disposal well with fluid type, volume and injection rates & press. Overflush by 125 bbl FIW at end of disposing fluids. Paul Figel Sr. Production Engineer Kyle Hammond Vice President Operations, Alaska Procedure 8-6-03 MGS C42-23 Cook Inlet, Alaska Leg 4, Conductor 25 APl No.: 50-133-20315 Spud: 3-13-78 Surf Csg: 13 3/8", 54.5/61 lb, K55. Set @ 2,578'. Cmt w/2,100 sx. Present Completion PLF 7-29-03 KB: 35' Water Depth: 73' MSL Tubing: 3 1/2", 9.2#, N80 @ 8,629'. 61 Jts 8R, 222 Jts BTC. Set 6-7-78 Item TVD M.D Ptro Port GLM I 1989 2033 935 3/16" GLM 2 3707 3907 925 3/16" GLM 3 5138 5438 910 3/16" GLM 4 6272 6628 900 3/16" GLM 5 7180 7596 935 1/4" GLM 6 7862 8314 920 1/4" GLM 7 8095 8561 955 5/16" Intermediate Csg: 7 5/8" 29.7/33.7 lb, N80. Set @ 8,822'. Cmt w/450 sx. Ball Valve @ 300' Guiberson Uni-Packer VII @ 8,575' Otis "X" Nipple (2.75" ID) @ 8,585' Otis "X" Nipple (2.75" ID) @ 8,617' Mule-shoe @ 8,628' Note: EOT is 5' inside 5-1/2" liner. Prod Liner: 5-1/2", 17 lb, N80. Set @ 9,848'. TOL @ 8,624'. Cmt w/210 sx. Sqz TOL w/150 sx. GR-GS: 8,675' & 8,679' (2 holes) WL Tagged Fill @ 9,368' on 7-22-03 HK-HN: 9,196'-9,215' HK-HN: 9,260'-9,332' HN-HR: 9,367'-9,503' HR-HZ: 9,527'-9,603' HR-HZ: 9,604'-9,667' PBTD: 9,753' MD (9,161'TVD) TD: 9,850' MD (9,306' TVD) Revised C42-23 Procedure Subject: Revised C42-23 Procedure Date: Tue, 6 Nov 2001 11:30:00 -0600 From: PauLFigel@xtoenergy.com To: tom_maunder@admin.state.ak.us (See attached file: C42-23 Scale CO Final Procedure REV1 .doc) Tom, let me know if you have any question on this. I made a couple changes to the 10-5 procedure, today, after what I saw on the C43-14 job last month. Biggest change was not using gas lift at all during the job to keep circulation. This well should circ fine w/water as the C43-14 did. Paul i ! Name: C42-23 Scale CO Final Procedure REVl.doc i ~C42-23 Scale CO Final Procedure REVl.docl Type: WINWORD File (application/msword) ~ Encoding: x-uuencode ~ IDescription: Mac Word 3.0 1 of 1 11/6/01 11:32 AM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon ~ Suspend ~ Operation shutdown Re-enter suspended well After casing ~ Repair well Plugging Time extension __ Stimulate X Change approved program Pull tubing ~ Variance ~ Perforate __ Other 2. Name of Operator ZTO ~ :[:nc, 3. Address 3000 N. Garfield, Ste 175, tw. id.la..-,d, TX 79705 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location ofwellatsurface Platform ~/~ L~g 4~/Conductor 25, 509' ~ & 1541' FE~ of Sec. 23/TS~, R13W, SM At top of productive interval 6. Datum elevation (DF or KB) 116' IF 7. Unit or Property name ~Lidd.3.e erooz~ ~ 8. Well number C42-23 ~/ 9. Permitnu~v~,er 78-0024/91-306 10. APInumber v~' 50-133-20315 @ 8654', 3043' FSL& 1882' FEb of Sec. 23, T8N, P,.13W, SM Ateffectivedepth Attotaldepth @9850', 3455' :~"~& 1941' :b'~of .Ek~=. 23, TSN, :R13W, SM 11. Field/Pool lvlU-.S/"F" & "G" Pools feet 12. Present well condition summary Total depth: measured true vertical 9850' 7feet 9306 ''/feet Plugs (measured) Effective depth: measured true vertical 9753 ' feet 9161' feet Junk (measured) Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented 2578' 13-3/8",54.5-61#, K-55 8822' 7-5/8",29.7-33.7#, N-80 1224' 5-1/2", 17#, N-80 measured 8654'-9667' true vertical Measured depth True vertical depth 8221'-9134' Tubing (size, grade, and measured depth) 3-1/2", 9.3#, N-80 @ 8629' Packers and SSSV (type and measured depth) 6;,,4herson Ik~i-~ VII ~ 8575' 2100SX 2578' 2492' 450SX 8822' 8346' 210SX 8624'-9848' 8158'-9304' RECEIVED OCT g 6 Z00! ,Alaska Oil & Gas Cons. Commission Anchorage 13. Attachments Description summary of proposal Detailed operations program ~ BOP sketch 14. Estimated date for commencing operation 11/13/01 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil X Gas Service Suspended __ 17. I hereb~fti~y that the for~in, g is true and correct to the best of my knowledge. Signed '.~~ ,~. ~ Title Productic~ En~ Date 10/24/01 (/ ' FOR COMMISSION USEONLY ~'~1 Conditions of approval: Notify Commission so representative may witness ,.~'(~X)~ ~. ~.~)~'~,~ ~ Approval No. ,--.~_~[ _ ~7 Plug integrity __ BOP Test '~ Location clearance __ Mechanical Integrity Test Subsequent form required 10- ~ ~,~ t-~ Approved by order of the Commission Camml/ Commissioner D at:u B M/i'~i/p~L[~/AT E I Form 10-403 Rev 06/15/88 ORIGINAL Revised C42-23 Procedure · Subje~:t: Revised C42-23 Procedure Date: Tue, 6 Nov 2001 11:30:00 -0600 From: Paul_Figel@xtoenergy.com To: tom_maunder@admin.state.ak.us (See,attached file: C42-23 Scale CO Final Procedure REV1 .doc) Tom, let me know if you have any question on this. I made a couple changes to the 10-5 procedure, today, after what i saw on the C43-14 job last month. Biggest change was not using gas lift at all during the job to keep circulation. This well should circ fine w/water as the C43-14 did. Paul ', { Name: C42-23 Scale CO Final Procedure REV1 .doc Type: WINWORD File (application/msword) i~C42-23 Scale CO Final Procedure REVl.doci Encoding: x-uuencode i~ Description: Mac Word 3.0 I of 1 11/6/01 11: 32 AM XTO Energy Inc. MGS C42-23 COOK INLET, ALASKA WELL DATA: SURFACE CASING: 13 3/8" 54.5, 61# K55. Set ~ 2,578'. Cmt w/2,100 sx. INTERMEDIATE CASING: 7 5/8" 29.7, 33.7#, N80. Set ~ 8,822'. Cmt w/450 sx. PRODUCTION LINER: 5 ½" 17#, N80, ~ 8,624 - 9,848'. Cmt w/210 sx. Sqz liner top w/150 sx. TUBING: 3 ½" 9.2#, N80, 61 Jts 8R, 222 Jts BTC PACKER: 7 5/8" Guiberson Uni-Packer VII ~ 8,575'. Set in June 1978. PERFORATIONS: GR-GS: 8,675 & 8,679' (2 holes) HK-HN: 9,196 - 9,215' HK-HN: 9,260 - 9,332' HN-HR: 9,367 - 9,503' HR-HZ: 9,527 - 9,603' HR-HZ: 9,604 - 9,667' 256' 160 Deg F 2,700 psi X Nipples: 2.75" ID ~ 8,585' & 8,617' Prod ~ 40 BOPD, 50 BWPD, 103 mcf/d, 1,092 mcf/d INJ ~ 540 psi Csg Press. Clean out scale fill and acid stimulation with Coil Tbg. NET PAY: BHST: BHP: SMALLEST ID: PRESENT STATUS: OBJECTIVE: NOTE: Slickline tagged up on fill ~ 9,662' (MD) on 10-16-00, which had gained 85' in height over 6 months since the prior gauge ring run in April 2000. Samples were analyzed and were found to be over 50% acid soluble. This well has a history of paraffin and calcium carbonate scale problems as noted from the Coil tbg acid clean-outs that were performed in 1985, 1987, and 1991. PROCEDURE: Two weeks prior to the workover, production operator will get 1 qt of oil off the C42-23 to Dowell for an acid / oil compatibility test. The acid is to contain 1,000 ppm ferric iron (Fe3) for testing. , MIRU the following: Materials Required: 10,500 gal (250 bbl)10% DAD Acid (25% xylene: 75% - 10% HCL) 500 gal 10% HCL Pickle Acid (Corrosion Inhibitor + Surfactant) 60 bbl Xanthan Gel Pill (2.5# / bbl Flo-Vis + Biocide provided by MI Drill Fluids) 1,800 bbl 3% KCL FIW Water (Friction Reducer Supplied by Dowell) ~ 19,000 lbs Powdered KCL & 1 gal / 100 bbl Safe Scav HS (Supplied by MI ) 180,000 scfNitrogen (Plus N2 bottles to purge reel after job) 2,000 lbs Soda Ash (Supplied by MI) Final Procedure REV1 1 1-O6-fll XTO Energy Inc. MGS C42-23 Cook Inlet, Alaska Equipment Required: Dowell 1 ~" CTU: Install press gauges on CT, CT annulus and 3 ½" tbg annulus. · 2 ea HP Triplex Pump: (1 for the CT pumping, 1 for fluid transfer) · N2 Unit · Jet Blaster Tool · Filter Skid (8 micron) · Acid Tanks for 250 bbl · 500 gal 10% HCL Pickle Acid Tank 250 bbl, 120 psi press control surface Surge Tank w/2" vent line · Return line w/choke manifold to 250 bbl Surge Tank & to Production Facilities } Manifold to contain a sample catcher to monitor fluids pH } Send "clean" returns to Production Facilities ~' Send live acid and or fluids containing scale or solids to Surge Tank - Neutralize w/Soda Ash before pumping to Disposal Well (C44-14RD) · Have H2S monitors for the sample catcher & Surge Tank · RU necessary lines to pickle coil with acid as specified in Step #4. No fluids are to be pumped overboard. Recovered wellbore materials will be tested for NORM and sent to onshore. Acid System to contain these additives (Conc. dependent on,acid / 0il eompatibili~ test): · 10% HCL (Acid to be titrated on location.) · 250 gpt Xylene · 4 gpt A260 Corrosion Inhibitor · 8 gpt L63 Iron Reducing Agent 5 ppt A179 Iron Reducing Activator 10 gpt U42 Iron Chelating Agent 15 gpt U74 Surfactant / Dispersing Agent for Xylene Non-Emulsifier / Anti-Sludge Additive 2. RU BOP's. Press test BOP's to 5,000 psi. Test treating lines to 6,000 psi. Job Max press is 5,000 psi. CTU operator to ensure all tools to be calipered before RIH. Smallest ID = 2.75" ~ X Nipples ~ 8,585' & 8,617'. 3. Hold safety meeting with all service & production personnel about the procedure, corrosive chemicals, and possible H2S exposure. , Prior to RIH, pickle the coil tbg string w/250 gal 10% HCL Pickle Acid (Corrosion Inhibitor + Surfactant). Flush with FIW to surface tank to be neutralized before disposing the fluid. Titrate for total iron to be less than 3,000 ppm. Repeat if necessary. CLEAN OUT HOLE: 5. With the CT annulus open, RIH w/Jet Blaster while pumping ~ 1.5 BPM slick 3% KCL FIW to PBTD ~ 9,753'. RIH @ 40 ft/min in the 3 ½" Tbg & slow to 20 a/min in the 5 ½" Liner. Slow the coil tbg rate & make 3 passes as the jetting tool passes over the 7 GLM's. (See attached Well Schematic.) Send clean returns to production. Returns containing solids and or acid must go to the surface return tank and vent the gas. Use auxiliary triplex pump to transfer circulated water down disposal well C44-14RD as needed. Be prepared to use acid if can not make progress into the hole. Use acid only when necessary. Final Procedure REV1 11-06-01 XTO Energy Inc. MGS C42-23 Cook Inlet, Alaska 6. Once CT tags up ~ 9,753', circ hole clean w/20 bbl Xanthan gel pill to surface followed with slick 3% KCL FIW ~ 1.5 BPM. ACID SPOT & ,SOAK,:, 7. With the CT annulus open & Jet Blaster starting ~ 9,700', lay 1,000 gal (24 bbl) 10% DAD acid from 9,700' to 8,650' while pulling up hole using slick 3% KCL FIW to displace. PU CT to 8,550' and SD. Let acid soak for 30 min. 8, Keeping the CT annulus open, run the CT down through the acid ~ 30 fdmin while circ slick 3% KCL FIW to surface ~ 1.5 BPM. prOCeed to 9,753'. Circ hole clean w/20 bbl Xanthan gel pill to surface followed with slick 3% KCL FIW. Send returning acid to Surge Tank. ACID WASH PERle'S: 9. Once the hole is clean, keep the CT annulus open and begin to acid wash perf's w/4,200 gal (100 bbl) 10% DAD Acid ~ 1 BPM, moving the Jet Blaster Tool at 10 ft/min from 9,680 - 9,180'. Make 1 pass up and l down ~ this rate covering perf's from: 9,196 - 9,667'. 10. With the Jet Tool ~ 9,753', circ hole clean w/20 bbl Xanthan gel pill to surface followed with slick 3% KCL FIW (~ 1.5 BPM. Once hole is clean, close the CT annulus. Do NOT mix any. friction reducer to FIW beyond this. step: ACID INJECTION JOB: 11. Keeping the CT annulus closed, inject 2,500 gal (60 bbl) 10% DAD acid into the perf's while making 1 pass across the interval from 9,680 - 9,180' while pumping ~ 1 BPM and moving the Jet Blaster Tool ~ 10 ft/min. SD pump. 12. PU to 8,690'. Inject 250 gal (6 bbl) acid while making 2 passes from 8,690 - 8,660' ~ 10 fdmin. Overflush w/6 bbl 3% FIW. 13. RIH to 9,180'. Inject 2,500 gal (60 bbl) 10% DAD acid into the perf's while making 1 pass across the interval from 9,180 - 9,680' while pumping ~ 1 BPM and moving the Jet Blaster Tool @ 10 ft/min. 14. 15. Finish pumping all acid ~ 9,680'. Over-displace acid by injecting 120 bbl 3% KCL FIW 50Q Foam (60 bbl 3% FIW + 51,000 scfN2) into the formation. Liquid rate = 0.75 BPM & N2 rate = 640 scf/m. (N2 Volume Factor = 850 scf/bbl space ~ 2,600 psi & 125 deg F.) Make 2 passes from 9,680 - 8,660' ~ 10 ft/min. Incr. tbg pull rate while moving from 9,180' to 8,690' (blank pipe). Open the CT annulus. PU coil tbg while jetting w/the remaining N2 (130,000 scf) taking returns to the surface surge tank. (Objective is to .only recover load of spent acid (+/- 125 bbl) and not tO kick offthe well0 SD N2 after acid load is recovered. Use the auxiliary triplex pump to unload the surface tank to the disposal well during jetting. SCALE INHIBITOR SQZ: 16. Once an effort has been made to recover most of the acid load, RIH w/CT to 8,660' while circ 3% KCL FIW ~ ½ BPM. Close the CT annulus. Sqz 5 bbl 10% Scale Inhibitor Ondeo Nalco EC6085A chemical into perf's ~ 8,675' & 8,679'. Overflush w/10 bbl 3% FIW. 17. RIH to 9,180'. Inject 43 bbl 10% Scale Inhibitor Ondeo Nalco EC6085A chemical 10 ft/min from 9,180 - 9,680'. Overflush the scale inhibitor w/60 bbl 3% KCL FIW while making I pass from 9,680' to 9,180'. POH with Coil Tbg w/o pumping fluid. Final Procedure REV1 11-06-01 XTO Energy Inc. MGS C42-23 Cook Inlet, Alaska 18. RD Coil Tbg Unit. Leave well SI for 8 hours after scale inhibitor squeeze before putting well back on production. 19. Start up gas lift and put well on production test. Monitor the well for 5 days taking readings every 1 hour for first 2 days. Take readings every other hour on days 3-5. Put well back into regular test rotation after 5 days. Record any use of the disposal well with fluid type, volume and injection rates & press. Overflush by 125 bbl FIW at end of disposing fluids. Paul Figel Production Engineer Doug Schultze Vice President Operations, Alaska Final Procedure REV1 11-06-01 WELL DATA: SURFACE CASING: INTERMEDIATE CASING: PRODUCTION LINER: TUBING: PACKER: PERFORATIONS: A XTO Energy Inc. MGS C42-23 KA ,,COOK INLET, ALAI 133/8 54.5,61#K55. Set @ 2,578., Cmtw/~00sx. 7 5/8" 29.7, 33.7#, N80. Set@8,,822. C//~w/450sx._ 5 ½',', 17#, N80, @ 8,624-9,848. Cmy/210 ax. Sqz liner top w/150 ax. 3 ½ 9.2#, N80, 61 Jts 8R, 222 Jts//~C 7 5/8" Guiberson Uni-P~cker V/J/V@ 8,575'. Set in June 1978. }Gi~-?SH~: a~ ~17¢6 &_ 98:26~, (2 J)61es) HK-HN: 9,260 - 9,332' HN-HR: 9,367 - 9,503' HR-HZ: 9,527 - 9,603 HR-HZ: 9,604- NET PAY: 256' BHST: 160 Deg F BHP: 2,700 psi SMALLEST ID: X Nipples: .75" ID @ 8,585' & 8,617' PRESENT STATUS: Prod @ 4 BOPD, 50 BWPD, 103 mcf/d, 1,092 mcf/d INJ @ 540 psi Csg Press. OBJECTIVE: Clean scale fill and acid stimulation with Coil Tbg. NOTE: Slickline tagged up on fill @ .662' (MD) on 10-16-00, which had gained 85' in height over 6 months since the prior gauge ring run in April Samples were analyzed and were found to be over 50% acid soluble. This well has a history of paraffin and :ium carbonate scale problems as noted from the Coil tbg acid clean-outs that were performed in 1985, 1987, 1991. PROCEDURE: Two weeks prior to the compatibility test. The acid is ', production operator will get 1 qt of oil off the C42-23 to Dowell for an acid / oil contain 1,000 ppm ferric iron (Fe3) for testing. MIRU the following: Materials Required: · 10,500 gal (2 bbl)10% DAD Acid (25% xylene: 75% - 10% HCL) · 500 gal Pickle Acid (Corrosion Inhibitor + Surfactant) · 60 bbl tan Gel Pill (3# / bbl Flo-Vis provided by MI Drill Fluids) · 1,800 bbl % KCL FIW Water (Friction Reducer Supplied by Dowell) > 19. lbs Powdered KCL & 1 gal / 100 bbl Safe Scav HS (Supplied by MI ) · 125,00 scl Nitrogen · 1,000 Soda Ash (Supplied by MI) Final Procedure 10-06-01 XTO Energy Inc. MGS C42-23 Cook Inlet, Alaska Equipment Required: · Dowell 1 ~A" CTU: Install press gauges on CT, CT annulus and 3 V2" tbg annulus. · 2 ea HP Triplex Pump: (1 for the CT pumping, 1 for fluid transfer) · N2 Unit · Jet Blaster Tool · Filter Skid (8 micron) · Acid Tanks for 250 bbl · 500 gal 10% HCL Pickle Acid Tank · 250 bbl, 120 psi press control surface Surge Tank · Return line w/choke manifold to 250 bbl Surge Tank & to )~ Manifold to contain a sample catcher to monitor fluids pH )~ Send "clean" returns to Production Facilities )~ Send live acid and or fluids containing scale or solids t before pumping to Disposal Well (C44-14RD) · Install H2S monitors on both the sample catcher & Surge T · RU necessary lines to pickle coil with acid as specified in 4/4. No fluids are to be pumped overboard. Recovered wellbore materials will be tested for NORM to onshore. Tank - Neutralize w/Soda Ash Acid System to contain these additives (Cone. de · 10% HCL (Acid to be titrated on location.) · 250 gpt Xylene · 2 gpt A260 Corrosion Inhibitor · 8 gpt L63 kon Reducing Agent · 5 ppt A179 Iron Reducing Activator · 10 gpt U42 Iron Chelating Agent · 15 gpt U74 Surfactant / Dispersing · Non-Emulsifier / Anti-Sludge · Acid Friction Reducer on acid / oil compatibility test): for Xylene 2. RU BOP's and test lines to 7,000 psi. press is 6,000 psi. CTU operator to ensure all tools to be calipered before RIH. Smallest ID = 2.75" @ Nipples @ 8,585' & 8,617'. 3. Hold safety meeting with all service production personnel about the procedure, corrosive chemicals, and possible H2S exposure. . Prior to RIH, pickle the coil tbg si Flush with FIW to surface tank 3,000 ppm. Repeat if nece~, w/250 gal 10% HCL Pickle Acid (Corrosion Inhibitor + Surfactant). be neutralized before disposing the fluid. Titrate for total iron to be less than CLEAN OUT HOLE: 5. Adjust the Gas Lift rate to ac] eve adequate returns up the coil tbg annulus. With the CT annulus open, RIH w/ Jet Blaster while pumping 1 - 1.5 BPM slick 3% KCL FIW to PBTD @ 9,753'. Slow the tbg rate as the jetting tool passes over theGLM's. (See attached Well Schematic.) Send clean returns to production. Returns containing solids or acid must go to the surface return tank and flare off gas. Use auxiliary triplex pump to transfer water down disposal well C44-14RD as needed. Final Procedure 10-06-01 October 24, 2001 F~~ N~E R Gy XTO Energy Inc. 3000 North Garfield Suite 175 Midland, Texas 79705 915-682-8873 915-687-0862 (Fax) Alaska Oil and Gas Conservation Commission Attn: Cammy Taylor 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 Subject: Request for the approval to perform a Coil Tubing Cleanout & Acid Stimulation on the C42-23 Well, in the "F & G" pools, in the Middle Ground Shoal Field, Platform C. Dear Ms. Taylor, XTO Energy Inc., operator of Platform C, requests that the Alaska Oil and Gas Conservation Commission (AOGCC) approve the workover on the C42-23 Well in the "F & G" pools. A coil tubing workover is necessary to cleanout fill in the wellbore as identified by slickline operations in October 2000, covering a portion of the HR-HZ zone. This well has a history of producing both calcium carbonate scale & paraffin seen by the 3 coil tbg xylene / acid jobs performed in 1975, 1987, and 1991. The C42-23 was naturally completed in June 1978. Within the first 4 years of production, several zones were re-perforated. In 1986, the GR-GS zone was tested w/ 2 shots and was never pursued for further development. The coil tbg treatment would involve cleaning out all the wellbore scale & fill and injecting acid into the "F & G" pools for stimulation purposes. The acid treatment would be followed with a scale inhibitor squeeze. In summary, XTO Energy requests the AOGCC permit the C42-23 Well be worked over to stimulate production. Please direct any operational questions to Paul Figel at (915) 620-6743. Questions of a reservoir, or geologic nature may be directed to Tim Smith, Reservoir Engineer (817) 885-2246 or Mike Langeler, Geologist (817) 885-2581. Please notify me at my number included above as soon as the approval has been granted. Thank you for your assistance. Paul L. Figel Production Engineer ORIGINAL RECEIVED Alaska Oil & Gas Cons. Commissior., Anchorage Cc: Doug Schultze Doug Marshall Tim Smith Mike Langeler List of Attachments: 1. Present Wellbore Diagram 2. Workover Procedure XTO Energy Inc. MGS C42-23 Cook Inlet, Alaska Once CT tags up @ 9,753', circ hole clean w/20 bbl Xanthan gel pill to surface fol FlW @ max pump rate below 6,000 psi. Be prepared to use acid if acid only when necessary. SD Gas Lift. with slick 3% KCL tess into the hole. Use ACID SPOT & SOAK: c~' 7. With the CT annulus open & Jet Blaster starting @ 9,700', lay 1,000 gal to 8,650' while pulling up hole using slick 3% KCL FIW to displace. for 30 min. bbl) 10% DAD acid from 9,700' CT to 8,550' and SD. Let acid soak Start up & adjust the Gas Lift rate to achieve adequate returns up open, mn the CT down through the acid while circ slick 3 % to 9,753'. Circ hole clean w/20 bbl Xanthan gel pill to surface returning acid to Surge Tank & flare off gas. coil tbg annulus. Keeping the CT annulus to surface @ max pump rate. Proceed with slick 3% KCL FIW. Send ACID WASH PERF'S: 9. Cont. to gas lift. Once hole is clean, keep the CT annu open and begin to acid wash perf's w/4,200 gal (I00 bbl) 10% DAD Acid @ 1 BPM, moving the Jet Tool at 10 ft/min from 9,680 - 9,180'. Make I pass up and 1 down @ this rate covering perf' s from: 9 9,667'. 10. With the Jet Tool @ 9,753', circ hole clean w/ Xanthan gel pill to surface followed with slick 3% KCL FIW @ max pump rate. Once hole is clean, cl e the CT annulus & SD Gas Lift. ACID INJECTION JOB: 11. Close the CT annulus. Inject 2,500 gal interval from 9,680 - 9,180' while pump. bbl) 10% DAD acid into the perf's while making I pass across the @ 1 BPM and moving the Jet Blaster Tool @ 10 ft/min. SD 12. PU to 8,690'. Inject 250 gal (6 w/6 bbl 3% FIW. :id while making 2 passes from 8,690 - 8,660' @ 10 ft/min. Overflush 13. RIH to 9,180'. Inject 2,500 gal from 9,180 - 9,680' while bbl) 10% DAD acid into the perf's while making I pass across the interval @ 1 BPM and moving the Jet Blaster Tool @ 10 fi/min. 14. Finish pumping all acid @ while making 1 pass 8,690' (blank pipe). 680'. Over-displace acid by injecting 100 bbl 3% KCL FIW into the formation from 9,680 - 8,660' @ 10 ft/min. Incr tbg pull rate while moving from 9,180' to down ball to open circ sleeve above the Jet Nozzle on last 30 bbl of flush. 15. Open the CT PU coil tbg & tag fl in with N2 taking bbl) and not to pump to up & adjust the Gas Lift rate to achieve adequate returns up the coil tbg annulus. level (+/-3,000' w/BHP = 2,700 psi). Cool down the Nitrogen pump. Begin to jet well tums to the surface surge tank. (Objective is to only recover load of spent acid (+/- 125 off the well.) SD Gas Lift & N2 after acid load is recovered. Use the auxiliary triplex surface tank to the disposal well during jetting. SCALE INHIBI }Z: 16. Once an has been made to recover most of the acid load, RIH w/CT to 8,660' while circ 3% KCL FIW @ V2 Close the CT annulus. Sqz 5 bbl 10% Scale Inhibitor Ondeo Nalco EC6085A chemical into perf's @ 8,6T & 8,679'. Overflush w/10 bbl 3% FIW. Final 10-06-01 X. TO Energy Inc. MGS C42-23 Cook Inlet, Alaska 17. RIH to 9,180'. Inject 43 bbl 10% Scale Inhibitor Ondeo Nalco EC6085A che~ 10 ft/min from 9,180 - 9,680'. Overflush the scale inhibitor w/60 bbl 3% 9,680' to 9,180'. POH with Coil Tbg w/o pumping fluid. @ 1 BPM while moving @ F1W while making 1 pass from 18. RD Coil Tbg Unit. Leave well SI for 8 hours after scale inhibitor s production. before putting well back on 19. Start up gas lift and put well on production test. Monitor for 4 days taking readings every I hour for 1st day and every other hour for next 3 days. Put well into regular test rotation after 4-5 days. Paul Figel ~ Production Engineer Doug Schultze Vice President Operations, Alaska Final Procedure 10-06-01 MGS C42-23 Cook Inlet, Alaska Leg 4, Conductor 25 APl No.: 50-133-20315 Spud' 3-13-78 Surf Csg: 13 3/8", 54.5/61 lb, K55. Set @ 2,578'. Cmt'd w/2,100' sx. Intermediate Csg: 7 5/8" 29.7/33.7 lb, N80. Set @ 8,822'. Cmt'd w/450 sx. Prod Liner: 5-1/2", 17 lb, N80. Set @ 9,848'. TOL @ 8,624'. Cmt w/210 sx. Sqz T©L w/150 sx. Present Completion Prepared by: PLF 9-28-01 KB: 105' Water Depth: 73' MSL Tubing: 3 1/2", 9.2#, N80 @ 8,629'. 61 Jts 8R, 222 Jts BTC. Set 6-7-78 ............. Port Otis BV 300' 300' GLM 1 1989' 2033' 971 3/16" GLM 2 3707' 3907' 956 3/16" GLM 3 5138' 5438' 936 3/16" GLM 4 6272' 6628' 916 3/16" GLM 5 7180' 7596' 972 1/4" GLM 6 7862' 8314' 955 1/4" GLM 7 8095' 8561' Orifice 5/16" Guiberson Uni-Packer VII @ 8,575' MD (8,109' TVD) PKR set 6-6-78 Otis "X" Nipple @ 8,585' MD (8,118' TVD) (2.75" ID) Otis "X" Nipple @ 8,617' MD (8,149' TVD) (2.75" ID) Mule-shoe Collar @ 8,628' MD (8,367' TVD) E.O.T. @ 8,629' MD (8,368' TVD) Note: E.O.T. is 5' inside 5-1/2" liner. GR-GS: 8,675' & 8,679' (2 holes) HK-HN: 9,196'-9,215' HK-HN: 9,260'-9,332' HN-HR: 9,367'-9,503' HR-HZ: 9,527'-9,603' HR-HZ: 9,604'-9,667' PBTD: 9,753' MD (9,161' TVD) TD: 9,850' MD (9,306' TVD) 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 July 15, 1994 Paul Huckabee, Prod Engr Shell Western E&P Inc. 601 W 5th Ave, Suite 800 Anchorage, AK 99501 Re: No-Flow Verification MGS Well # C-42-23 PTD 78-024 Dear Mr. Huckabee: At Shell's request, on April 21, 1994, our Inspector Bobby Foster witnessed a no-flow test on Middle Ground Shoal well # C-42-23. Gas lift to the well was shut off at 4:00 PM, 7/13/94 and the annulus bled down. On the 14th the well was opened to the test separator and was later bled to atmosphere. The well was monitored by our Inspector in flowing conditions for one hour and shut in for 1.5 hours. The Inspector concluded the well was not capable of unassisted flow of hydrocarbons. The Commission hereby authorizes removal of the subsurface safety valves from MGS well # C-42-23 (PTD 78-024), on the condition that the low pressure sensor and surface safety valve must be maintained in good condition and, if for any reason the well again becomes capable of unassisted flow, the subsurface safety valve must be reinstalled and maintained in good working condition. Sincerely, Blair E. Wond~l PI Supervisor Morris Dunkley Bobby Foster bew/nlmg4223 MEMORANDUM TO: THRU: State of Alaska Alaska Oil and Gas Conservation Commission .David Jo~ Chairma~ Blair VVondzell,~ P. I. Supervisor FROM: Bobby FosS+ SUBJECT: Petroleum Inspector DATE: July 14, 1994 FILE NO: 1V91GNBD.doc No Flow Test Shell - MGS - C42-23 Platform C Thursday, July 14, 1994.: I traveled Shell's Platform C this date after completing the meter proving, the subject of another report, and witnessed the No Flow Test on well C42-23. I arrived on platform and met with Tom Reese and Garry Daniels, Shell reps. and was informed that the gas lift system had been cut off of well the previous evening at about 4:00PM and the gas was bled off of the casing down the flow line to the test separator. At 1:00 AM - 7/14/94 - a chad was placed on the recorder on separator and the manual dump was opened to the non pressured storage tank. As the attached chad shows the well pressure dropped from 80 +- psig to 0 psig in approximately 1 hour. I went to the well room and checked the well head valves and the separator valves. I observed the well for 1 hour and then closed the wing valve to see if the well would build up any pressure. At the end of 1.5 hours I opened the well up and on a one half inch needle valve and could feel-~rVa slight blow of gas. I observe the well for another one half hour and the well was not making an.~ gas or fluid. I recommend to the CommisSion that this well be placed in a" No Flow" status. Summan/: I witnessed the satisfactory No Flow Test on Shell's C42-23 well on the C platform in the Middle Ground Shoal Oil Pool. Attachment: No Flow Test Chad NO. MO L-~O · TIME ~M TAKEN OFF TIME ~ DATE ~ DATE LOOATION ~ g Shell Western E&P Inc. 601 West Fifth Avenue · Suite 80 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 C42-23 Enclosed are duplicates of the Subsequent Report for the recently completed stimulation work of Middle Ground Shoal well C42-23. The operations were completed on October 20, 1991. If you need additional reports or information, please contact Mr. Paul Huckabee at (907) 263-9646. Very Truly Yours, /~ R. G. Blackburn Manager Alaska Operations Western Division RGB/SBBM/dlw Enclosures SBBM~121691C.WP5 RECEIVED c 2 0 1991 Gas Cons. Commission Anchora[Te .... STATE OF ALASKA ---- AL ,-~ OIL AND GAS CONSERVATION COMMk. ~1 REPORT OF SUNDRY WELL OPERATII 6j_N A [ 1. Operations pelformed: Operation shutdown __ Stimulate X Plugging__ Perforate __ Pull tubing __ Alter casing__ Repair well __ Other 5. Type of Well: 6. Datum elevation (DF or KB) 2. Name of Operator Shell Western E&P Inc. Development X 116' DF feet 3. Address 601 W. 5th Avenue, Suite 810 Exploratory__ 7. Unit or Property name Anchorage, AK 99501 Stratigraphic__ Middle Ground Shoal Service 8. Well Number 4. Location of well at surface Platform C, Leg 4, Conductor 25,509'FSL and 1541'FEL of C42-23 Sec. 23, T8N, R13W, SM 9. Permit number/approval number At top of productive interval @8654', 3043'FSL and 1882'FEL of Sec. 23, T8N, R13W, SM 78-0024/91-306 10. APl number At effective depth 50-133-20315 11. Field/Pool At total depth @9850', 3455'FSL and 1941'FEL of Sec. 23, T8N, R13W, SM MGS/"F" & "G" Pools 12. Present well condition summary Total depth: measured 9850 feet Plugs (measured) true vertical 9306 feet Effective depth' measured 9753 feet Junk (measured) true vertical 9161 feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor Surface 2578' 13-3/8", 54.5-61#, K-55 2100 sx 2578' 2492' Intermediate 8822' 7-5/8", 29.7-33.7#, N-80 450 sx 8822' 8346' Production 1224' 5-1/2", 17#, N-80 210 sx 8624' - 9848' 8158' - 9304' Liner Perforation depth: measured 8654'- 9667' true vertical 8221' - 9134' R'~""~, ~E ~ V E D Tubing (size, grade, and measured depth) 3-1/2", 9.3#, N-80 @ 8629' b EC 2 0 1991 Packers and SSSV (type and measured depth) Guiberson Uni-packer VII @ 8575'Alaska 0il & I~as Cons. Commission Anch.~ra~c, 13. Stimulation or cement squeeze summary ntervals treated (measured) 9196'- 9667' Treatment description including volumes used and final pressure CTU Acid soak, wash, squeeze. Total acid volume 147 bbls. Squeeze ISIP = 3000 psi. 14. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 32 31 82 710 70 Subsequent to operation 43-: 0 227 835 80 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run __ Oil × Gas Suspended Service Daily Report of Well Operations X m __ __ 17. I hereby certity that the toregoing is true ann correct to the best of my Knowleclge Form 10-404 Rev ¢6/15/88 SUBMIT IN DUPLICATE DAILY REPORT WELL= C42-23 DAILY SUMMARY - (from 0600 hrs prior day to 0600 hrs) 10/20/91 - ASSIGN COIL TUBING PROJECT FROM C24-23 @ 1800 hrs, 10/19/91 - RIH W/2.5" "WAVY BOTTOM" MILL, 2.0625" PDM, DBLCV ASSEMBLY. - NO SIGNIFICANT SCALE ENCOUNTERED TO PBTD @ 9765' (CT/RKB) - PUMP 5 bbl GEL POLYMER SWEEP. CHASE SWEEP & POH. - RIH W/2.5" JET "SWIRL" WASH NOZZLE, DBLCV. - JET WASH WHILE RIH, WORK ALL GLMS 3 TIMES WITH 25' ABOVE AND BELOW (WASH OFF LOOSE SCALE). EXTRA WASHING ON GLM #7. - LOCATE NOZZLE @ 9667' (BOTTOM OF HR-HZ). PUMP 10.5 bbls 7.5% HCL, CHASE W/5 bbl GEL POLYMER PILL TO SPOT ACID IN PERFORATED INTERVAL. PUMPING ACID & GEL @ REPORT TIME. 10/21/91 - LOCATE NOZZLE @ 9667', SPOT 10.5 bbls 7.5% HCL SOLUTION F/9667' T/9196' W/5 bbl GEL XCD POLYMER SWEEP. - ACID SOAK PERFORATIONS FOR 30 mins. - PUMP 23.8 bbls OF 25:75 XYLENE:ACID PAD FOLLOWED BY 18.7 bbls FIW W/EOCT @ 8629' TO SOAK PAD ACROSS LOWER THIRD OF PRODUCTION TUBING. SOAK FOR 30 mins. - PUMP 18.7 bbls OF FIW TO DISPLACE ACID PAD TO SECOND THIRD SECTION OF PRODUCTION TUBING. SOAK FOR 30 mins. - PUMP 18.7 bbls OF FIW TO DISPLACE ACID PAD ACROSS TOP THIRD SECTION OF PRODUCTION TUBING. SOAK FOR 30 mins. - PUMP 60 bbls + TO DISPLACE SOAK ACID & XYLENE:ACID PAD ALL TO DECK SURGE TANK FOR ISOLATION & DISPOSAL. - RIH & TAG FILL @ 9754', WASH T/9765' (11' OF FILL). PUMP 15 bbl GEL POLYMER SWEEP @ 62 gpm & FIW TO DISPLACE FILL (FILL RESULTING FROM ACID SOAK). - LOCATE EOCT T/9667'. SPOT TO EOCT 24 bbl OF 7.5% HCL SOLUTION @ BEGIN PUMPING @ lbpm, HOISTING @ 20 fpm TO JET ACID WASH PERFORATIONS F/9667' T/9193'. - NOTE: WHILE RIH FOR SQUEEZE, OBSERVED TUBING WEIGHT LOSS (1200#) THROUGH 9520' TO 9615' INTERVAL. WEIGHT WAS RECOVERED BEYOND THIS POINT SIGNIFICANT CROSS FLOW MAY BE PRESENT. RECEIVED DEO 0 1991 Alaska 011 & Gas Cons. Commission Anchorage DAILY REPORT WELL= C42-23 10/21/91 - NOTE: AFTER ACID SOAK & JET WASH THROUGH (CONT'D) PERFORATIONS, SHUT-IN WELLHEAD PRESSURE ROSE TO 450 -500#. NO GAS WAS PRESENT. POSSIBLY CAUSED BY OIL OR SALTWATER FLOW EXPOSED FROM ACID TREATMENT. - LOCATE EOCT @ 9667' (BOTTOM PERFORATION). - CONDUCT PRESSURE INTEGRITY AND INJECTIVITY TEST. CSG @ 310#, PTbg @ 3350# @ 31 gpm (9 bbls). GOOD. - SPOT 22.7 bbls 7.5% HCL ACID SOLUTION @ EOCT (9667'). CLOSE IN WELL, PUMP/SQUEEZE 88 bbls TOTAL ACID TO FORMATION, DISPLACE ACID WITH 115 FIW. - SQUEEZE DATA: CSG# CT# PTbg# GPM ISIP = 3000# LOW 310 4600 2700 28 5m SIP = 2225# HIGH 340 5000 3480 40 10m FSIP= 2000# - POH W/J/W NOZZLE. R/D. CT EQUIP RELEASED @ 1900 hfs, 10/20 RECEIVED DEC ~ 0 AJa$~.OJi & Gas Cons. i.;omt~Jssiol~ ~chorage October 7, 1991 Shell Western E&P Inc.ii~ 601 West Fifth Avenue · Suite 800 Anchorage, Alaska 99501 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Gentlemen' SUBJECT: SUBMISSION OF APPLICATION FOR SUNDRY APPROVAL FOR MIDDLE GROUND SHOAL WELL NO. C42-23 Enclosed in triplicate is the application for Sundry Approval to perform a coiled tubing clean out/acid treatment workover on MGS Well No. C42-23. The workover is anticipated to begin on October 18, 1991. If you have any questions, please call Mr. Paul Huckabee at (907) 263-9646. Very Truly Yours, V. F. Un§~r Di¥~s~on Drilling £n§ineer gl aska Division VEU/slm Enclosures RECEIVED OCT. 9 1991 ~las'~,'Oil.&~Gas Coas. ~mml~ql,, AOGCC\SUNDRY.DOC STATE OF ALASKA AL. ,,~r(A OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon Alter casing __ Change approved program __ 2. Name of Operator Shell Western E&P Inc. 3. Address 601 West 5th Avenue, Suite 800 Anchorage, AK 99501 Suspend Repair Well Operation shutdown Re-enter suspended well Plugging__ Time extension Stimulate X -- Pull tubing Variance Perforate __ Other 5. Type of Well: Development X Exploratory Stratigraphic Service 4. Location of well at surface At top of productive interval At effective depth At total depth Platform C, Leg4, Conductor 25, 509' FSL & 1,541' FEL of Sec. 23, T8N, R13W, S.M. @ 8,654', 3,043' FSL & 1,882' FEL of Sec. 23, T8N, R13W, S.M. @9,850', 3,455' FSL & 1,941' FEL of Sec. 23, T8N, R13W, S.M. 12. Present well condition summary Total depth: measured true vertical 9,850 feet 9,306 feet Effective depth: measured 9,753 feet true vertical 9,161 feet Plugs (measured) Junk (measured) 6. Datum elevation (DF or KB~ 116' DF feet 7. Unit or Property name Middle Ground Shoal 3. Well number C42-23 9. Permit number 78-0024 10. APl number 50-133-20315 11. Field/Pool MGS/"F" & "G" Pools Casing Length Size Structural Conductor Surface 2,578' 13-3/8",54.5-61#, K-55 Intermediate 8,822' 7-5/8",29.7-33.7#,N-80 Production 1,224' 5-1/2", 17#,N-80 Liner Cemented Measured depth True vertical depth 2,100sx 2,578' 2,492' 450sx 8,822' 8,346' 210sx 8,624'-9,848' 8,158'-9,304' Perforation depth: measured 8,654'-9,667' true vertical 8,221 '-9,134' Tubing (size, grade, and measured depth) 3-1/2", 9.3#, N-80 @ 8,629' Packers and SSSV (type and measured depth) Guiberson Uni-packer VII @ 8,575' RECEIVED OCT - 9 1991 Alaska 0il & Gas Cons. C0mmtsst~t~ ~nchorage 13. Attachments Description summary of proposal Detailed operations program X_~ BOP sketch 14. Estimated date for commencing operation 10/18/91 Oil X 16. If proposal was verbally approved -- l, Service Name of approver Date approved 7. I hereby certify that the foregoing is true and correct to the best of my knowledge 15. Status of well classification as: Gas Suspended '~/~[gned ~V" /-~'' (l~yf"~._Y Title Division Drilling Engineer FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity._ BOP Test Location clearance Mechanical Integrity Test__---Subsequent form require--d 10- Z/'-~ ~. ORIGINAL SIGNED BY LONNIE C, SMITH Approved by order of the Commission Date 10/07/91 Approval No.~// Commissioner Date //~) ~.- ~'_ ~' / Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE MIDDLE GROUND SHOAL WELL No. C42-23 COILED TUBING CLEAN OUT XYLENE/ACID TREAT PRESENT STATUS: Producing via gas lift Last test (9/28/91) - 20 BOPD, 112 GROSS, 82% H20 cut Paraffin and tubing scale problems indicated via slickline OBJECTIVES: 1) Remove paraffin and tubing scale via Xylene/Acid tubing wash. 2) Acid Treat Hemlock via 7.5% HCl soak/jet wash/squeeze. NOTES: - 3-1/2" 9.3# N-80 tubing, EOT @ 8629' - 5-1/2" 17# liner, TOL @ 8620' - Minimum restrictions - 2.750" ID Otis "X" nipples @ 8585' and 8617' - A SSSV cannot be successfully installed for operation. - Fill tagged at 9645' during slickline operations 8/28/89. (bottom HR-HZ perf at 9667' so ~ 22' fill) - "PX" plug body pulled from 8555' 7/27/91. - No indications of fish in casing via review of Anchorage Engineering files. RECOMMENDED PROCEDURE: (Refer to Attachment No. 1 for mechanical equipment details) 1. One week prior to scheduled rig-up, test mechanical integrity of all critical components (ie., swab valve, wing valve, tubing spool valve, etc.). Pressure test all critical components to 3500 psi. Replace or repair defective components. 2. Prior to CTU Rig Up, review all data files for information on junk in hole, fill indications, tubing blockages, and tubing ID restrictions. The following responsibilities are identified. Anchorage Well Files - Production Engineering Platform Well Files - Operations Foreman/SWEPI CTU Supervisor Wireline Log Book - Wireline Operator/Operations Foreman 3. The SWEPI CTU Supervisor should ensure all equipment to be run in the hole is calipered for both ID and OD, and that a complete dimensional drawing of each component is on file. MIDDLE GROUND SHOAL No. C42-23 COILED TUBING CLEAN OUT XYLENE/ACID TREATMENT · · NOTE: · · · 24 hours before CTU is scheduled for RU on this well, fill wellbore via annulus with Filtered Inlet Water (FIW). Take returns via circulation to production. Do Not inject more than 400 bbls FIW without contacting Production Engineering or Manager Alaska Operations to discuss. Do Not access FIW directly downstream of the waterflood DE filter. Access FIW from downstream of the CUNO cartridge filters. Hold safety meeting with Arctic Recoil, Halliburton, and all other service company and platform personnel to discuss the proposed operations. Emphasize safety concerns with the chemicals to be used and with H2S during acidizing operations. H2S concentrations of 150 - 250 ppm are not uncommon in spent acid returns during MGS acid treatments. Ensure crown valve is closed. RU Arctic Recoil CTU with 1-1/2" coiled tubing and CTU assist pump. Install double check valves and hydraulic disconnect on coiled tubing. RU BOPE and flow "T". (NOTE: Equip CTU BOPE stack with blind rams, shear rams, and pipe rams.) Test CTU BOPE and coiled tubing to 5000 psi against swab valve and CTU stripper rubbers. Bleed coiled tubing pressure to negative test the double check valves. RU Halliburton with 125+ bbls 7-1/2% HCl acid and 1000 gals 25:75 PAD (Xylene/Acid dispersion system). Ensure all hazardous materials are properly manifested in accordance with Department of Transportation Regulations. Include the following additives in the acid. - 0.5% HAI-85 Corrosion Inhibitor, - 0.2% LoSurf-300 Non-Emulsifying Agent/Surfactant, - 20#/1000 gal FERCHEK-A iron chelating agent. Include the following additives in the 25:75 PAD. - 750 gals 7-1/2% HCl acid, - 250 gals Xylene, - 0.5% HAI-85 Corrosion Inhibitor, - 1.0% WS-36 Emulsifier (for oil external emulsion), - 20#/1000 gal FERCHEK-A iron chelating agent. RU valve manifold so the CTU assist pump can quickly access the acid, PAD, and FIW independently. Filter all fluids pumped downhole through the 3 micron cartridge filters on the Arctic Recoil CTU assist pump. page 2 RECEIVED Alask~ Oil & Gas Cons. ~ncborag~. MIDDLE GROUND SHOAL No. C42-23 COILED TUBING CLEAN OUT XYLENE/ACID TREATMENT 9. RU instrumentation to monitor injection rate, coiled tubing injection pressure, coiled tubing (CT) x injection tubing (tbg) annulus pressure, and tbg x casing (csg) annulus pressure. For acid squeeze operations, the CT x tbg annulus and tbg x csg annulus should be monitored via a two pen chart recorder. Send annotated charts to Production Engineering in Anchorage. 10. Ensure surface handling equipment is installed to safely and efficiently handle return acid, Xylene, and H2S for either disposal into C44-14RD or treatment and transfer to Production (see Attachment No. 2). CLEAN OUT & ACID SOAK PERFORATIONS 11. RIH with 2-1/2" flat (or wavy) bottom mill, 2-1/16" Positive Displacement Motor (PDM), double check valves, and hydraulic disconnect sub on 1-1/2" coiled tubing to top of fill (last tagged 8/28/89 @ 9645'). Clean out any fill across perfs to PBTD 9753'. NOTE: If hard scale is encountered within the HR-HZ perforation interval, do not try to clean out any deeper without approval of Manager Alaska Operations. Top HR-HZ perf at 9527t, bottom perf at 9667'. 12. Mix a 5+ bbl polymer gel pill in FIW with 3#/bbl "XCD" polymer. At the maximum rate possible, without exceeding 5000 psi on the coiled tubing or 3500 psi on the coiled tubing x injection tubing annulus, pump/circulate a 5+ bbl "XC" polymer pill sweep to clean up any debris from the wellbore. POOH with PDM & mill. 13. RIH with 2-1/2" swirl type jet nozzle, double check valves, and hydraulic disconnect sub on coiled tubing to the bottom HR-HZ perf at 9667'. NOTE: Coiled tubing length = 14200 1-1/2" coiled tubing capacity = (1.597 bbls/1000')*14200' = 22.68 bbls CT x 5-1/2" 17# csg (HK - HZ) = (9667 '-9196') * 0.021060 = 9.9 bbls CT x 3.5" capac' EOT - surf = (8629'- 0') * 0.006510 = 56.2 bbls page 3 RECEIVED 00-[ - 9 1991 Alaska 0il & Anchorage MIDDLE GROUND SHOAL No. C42-23 COILED TUBING CLEAN OUT XYLENE/ACID TREATMENT CT x Wellbore annulus capac' = 0.02106 bbl/ft*(9667-8629') + 0.00651 bbl/ft* 8629' = 78.1 bbls 14. 15. 16. Conventionally circulate 10.5 bbls 7-1/2% HCL followed by 22.6 bbls FIW to displace the acid out of the end of the coiled tubing (EOCT). The acid volume should cover the interval from the bottom HR-HZ perf at 9667' to the top HK-HN perf @ 9196'. SD pump and let acid soak for at least 30 minutes. Mix a 5+ bbl polymer gel pill in FIW with 3#/bbl "XCD" polymer. At the maximum rate possible, without exceeding 5000 psi on the coiled tubing or 3500 psi on the coiled tubing x injection tubing annulus, pump/circulate a 5+ bbl "XC" polymer pill sweep to clean up any debris from the wellbore. Divert all acid returns to the surge vessel. Monitor vessel for H2S escapement. Pump contaminated fluid to C44-14RD disposal well to ensure adequate surge vessel capacity for continuing coiled tubing operations. Flush disposal well with a minimum of 100 bbls FIW to overflush perforations. Refer to Attachment No. 2A for Disposal Guidelines and record disposal operations data. 17. 18. XYLENE/ACID WASH TUBING PU EOCT to the EOT at 8629'. a) Spot/circulate 23.8 bbls (1000 gal) 25:75 Xylene:Acid PAD followed by 18.7 bbls FIW to place the PAD across the lower third of the production tubing. SD pumps and let solvent/acid soak for a minimum of 30 minutes. b) Pump an additional 18.7 bbls FIW to place the PAD across the middle third of the production tubing. SD pumps and let solvent/acid soak for a minimum of 30 minutes. c) Pump an additional 18.7 bbls FIW to place the PAD across the top third of the production tubing. SD pumps and let solvent/acid soak for a minimum of 30 minutes. d) Pump an additional 60 bbls FIW to displace wellbore clean. Pump contaminated fluid to C44-14RD disposal well to ensure adequate surge vessel capacity for continuing coiled tubing operations. Flush disposal well with a minimum of 100 bbls FIW to overflush perforations. REC£1VED page 4 OC'F - 9 199 Alaska 0il & Gas Cons. Anchorage MIDDLE GROUND SHO]%L No. C42-23 COILED TUBING CLEAN OUT XYLENE/~CID TREATMENT 19. JET WASH PERFORATIONS WITH ACI~ Locate EOCT at bottom HR-HZ perf at 9667'. Pump circulate at 1 BPM, while, reeling coiled tubing at 20 feet/min, to jet wash the perforations and wellbore from 9667' to the top HK-HN perf @ 9196' (will require ' 24 bbls 7-1/2% HCL). Additionally, wash all scale indications observed in the tubing during clean out. Displace circulate with a minimum of 100 bbls FIW to clear contaminated fluid from coiled tubing and wellbore. Divert all contaminated returns to the surge vessel for disposal. 20. 21. ACID SQUEEZE STIMULATION RIH and locate EOCT at the bottom HR-HZ perf @ 9667'. Spot circulate 22.7 bbls 7-1/2% HCL (with above additives) to the EOCT. Close coiled tubing annulus at the flow "tee". Pump/squeeze 67.3 bbls additional acid (90 bbls acid total) followed by 115 bbls FIW to overdisplace the acid into the perforations (by ' 90 bbls). Do not exceed 3500 psi surface pressure on the coiled tubing x injection tubing annulus. Coordinate with Production Operator to monitor tbg x csg annulus during squeeze operations. NOTE: Pump acid at the maximum rate possible without exceeding the pressure constraints. POOH. RD CTU. Gas lift well to production and test. Change out GLV's as necessary to optimize lift operation. 7 COMPLETION EQUIPMENT DETAIL SHEET MGS C42-23 7/21/87 NO. ITEM APPROXIMATE TVD. MD. PSI OR 1. BALL VALVE 2. GAS LIFT MANDREL #1 3. GAS LIFT MANDREL #2 4. GAS LIFT MANDREL #3 5. GAS LIFT MANDREL #4 6. GAS LIFT MANDREL #5 7. GAS LIFT MANDREL #6 8. GAS LIFT MANDREL #7 9. GUIBERSON UNI-PACKER VII 10. OTIS "X" NIPPLE 11. OTIS "X" NIPPLE 12. MULE-SHOE COLLAR E.O.T. NOTE: E.O.T. is 9' inside 5 1/2" liner CASING 7 5/8", 33.7#, 0- 8823' 5 1/2", 17#, 8620- 9848' PBTD = ~t!~fr7-' ~ ?~'~ ' TD = 9850' TUBING 3 1/2", 9.3#, N-80 @ 8629' PERFORATED ZONE GR-GS HK-HN HK-HN HN-HR HR-HZ HR-HZ 300 300 1989 2033 935 3/16 3707 3907 925 3/16 5138 5438 910 3/16 6272 6628 900 3/16 7180 7596 935 1/4 7862 8314 920 1/4 8095 8561 955 5/16 8109 8575 8118 8585 8148 8617 8159 8628 8160 8629 GROSS INTERVAL 8654-8689' 9196-9215' 9260-9332' 9367-9503' 9527-9603' 9604-9667' MIDDLE GROUND SHOAL NO. C42-23 COILED TUBING CLEAN OUT XYLENE/ACID TREATMENT ATTACHMENT NO. 2 CTU SURFACE HANDLING EOUIPMENT FOR RETURN FLUID TREATMENT OR DISPOSAL RU 250 bbl, 120 psi pressure contained surge tank for containment of contaminated fluid returns. RU return line choke manifold to take returns from the flow "tee" to either the 250 bbl surge tank or the group production separator. RU a sampling valve at the choke manifold to monitor pH of the returns fluid. All uncontaminated fluids can go directly to the group production separator. Divert all contaminated fluid to the surge tank for processing. · RU an injection pump to transfer contaminated fluid from the surge tank to the C44-14RD disposal well at an expected injection rate of 3 BPM @ 1500 psi. Manifold pump intake with FIW access, in addition to the surge tank access, to overdisplace all contaminated fluid with a minimum of 100 bbls FIW flush. NOTE: Halliburton Operator must keep a detailed record of date, time, shut-in pressure before injection, injection rate, fluid type, beginning & ending injection pressure, Instantaneous Shut-In Pressure (ISIP), final shut-in pressure after injection, and volume each time fluid is pumped into C44-14RD. Refer to Attachment No. 2A for Disposal Guidelines and record disposal operations data on the attached form. · RU H2S monitoring/detection equipment at the circulating choke and surge tank. Coordinate with SWEPI Production Operator to sample and monitor fluid returns and treat if necessary. · Install emergency blowdown lines for the surge tank. One from the pressure relief valve to blowdown fluids to the group production separator and one via a burst plate relief to the flare. · RU a gas flare line from the gas vent and burst plate relief of the surge tank to the platform flare. Install a flame arrester in the gas flare line. NOTE: Refer to Attachment No. 3 and follow the "Guidelines for Handling Backflowed and Circulated Fluids For Discharge" for all returns not disposed of in C44-14RD. The Onshore Operator should be notified and prepared to divert any transferred contaminated fluid to the holding tanks. This will allow further dilution and processing of any contaminated fluid prior to processing through the plant for discharge. page 7 MIDDLE GROUND SHOAL No. C42-23 COILED TUBING CLEAN OUT XYLENE/ACID TREATMENT ATTACHMENT NO. 2A C44-14RD DISPOSAL PROCEDURE GUIDELINES · · · · · Pump Operator must keep a detailed record of date, time, fluid description, shut-in pressure before injection, injection rate, beginning & ending injection pressure, Instantaneous Shut-In Pressure (ISIP), final shut-in pressure after injection, and volume each time fluid is pumped into C44-14RD. Complete the attached Disposal Record Form (on following page) to document all disposal activity. Establish Filtered Inlet Water (FIW) injection into C44-14RD at a minimum injection rate of 2 BPM. Maximum injection rate is 5 BPM. Maximum injection pressure is 3500 psi without consulting Engineering or Manager Alaska Operations. If injectivity is acceptable, close FIW access and open pump intake to disposal fluids. Pump disposal fluids into C44-14RD at a minimum injection rate of 2 BPM. Maximum injection rate is 5 BPM. Maximum injection pressure is 3500 psi unless injectivity drops below 2 BPM. If injectivity drops below 2 BPM at 3500 psi, increase pressure up to 4500 psi maximum injection pressure. Shut down pumps immediately if pressure exceeds 4500 psi or "screen-out" conditions are apparent! Close disposal fluid access and open pump intake to FIW to flush disposal fluid with a minimum of 100 bbls FIW (over-flush wellbore capacity by a minimum of 25 bbls). Shut down disposal operations, record ISIP, and monitor C44-14RD fall-off pressure for 30 minutes. Record all data on attached C44-14RD Disposal Record Form. Send a copy of the completed form to Production Engineering in Anchorage. Retain a copy of the form for the Platform files. page 8 MIDDLE GROUND SHOAL No. C42-23 COILED TUBING CLE~N OUT XYLENE/ACID TREATMENT ATTACHMENT NO. 2A (continued) C44-14RD DISPOSAL RECORD FORM Send a copy of the completed form to Production Engineering in Anchorage. Retain a copy of the form for the Platform files. 30 MIN PRIOR BEGIN END AFTER FLUID SI INJ. INJ. INJ. INJo SI DATE TIME DESCRIPTION PRESS RATE PRESS VOLUME PRESS ISIP PRESS (psi) (BPM) (psi) (bbls) (psi) (psi) (psi) page 9 MIDDLE GROUND SHOAL No. C42-23 COILED TUBING CLEAN OUT XYLENE/ACID TREATMENT ATTACHMENT No. 3 PROCEDURES FOR HANDLING BACKFLOWED AND CIRCUT.~TED FLUIDS FOR DISCHARGE Ail backflowed and circulated fluids, and not disposed of via C44-14RD, must be routed through the test separator prior to being Sent to the Onshore Facility for discharge. Emulsion breaker should be added as required. Bottle testing is recommended to determine the concentration of breaker. Monitor fluids for H2S and add appropriate scavenging chemicals as required. Note: Ensure any acid treatment fluids that are circulated or backflowed are neutralized prior to sending to the production separator. To satisfy EPA requirements, if the amount of fluid exceeds 250 bbls at one time, the Onshore Operator must take samples of all completion and/or well treatment fluids at the onshore discharge line. Samples must be sent to C&G labs in Anchorage for oil/grease and pH analysis. The Onshore Operator should label samples with description of fluid and date, such as: "Fluid returns from C42-23 acid treatment - lO/XX/91". Notify Onshore Operator when the fluid is being sent. Use the following calculation to determine when the samples need to be caught. Pipeline Delay = 2660 bbl Gross Daily Prod "C" (bbl) + Workover fluid slug (bbl) x 24 hrs = hrs Onshore Facility 1000 bbl Delay = -- Gross Daily Prod "A" "C" and "Baker" (bbl) x 24 hrs = hrs Total time between slug shipment and sample time = hfs NOTE: Because the operations may result in a significant quantity of contaminated return fluids, the Onshore Operator should be notified and prepared to divert the transferred fluid to the holding tanks. This will allow further dilution and processing of any contaminated fluid prior to processing through the plant for discharge. page 10 TELECOPY NO: (907) 270-7542 September 20, 1990 Mr. Wary Blackburn Division Operations Manager Shell Western E&P Inc. 601 W 5th Ave Ste 800 Anchorage, Alaska 99501 Re: No Flow Test Shell Platform "C" Well No. C-42-23 Middle Ground Shoal Dear Mr. Blackburn: On April 5, 1990 Bobby Foster, a representative of the Commission witnessed the no-flow test on the subject well. A review of the test data indicates that this well is no longer capable of unassisted flow of hydrocarbons to the surface. The Co~ission hereby authorizes removal oi the subsurface safety valve from well no. C-42-23, on condition that should any subsequent operations be performed that may alter the unassisted flow condition of the well, another no-flow test would be conducted to verify countinued no-flow status ~-or that well. Sincerely, Lonnie C. Smith C o~is s ioner BY O~ER OF THE COMMISSION dlf :N. PfI'M. 1 CC: SWEPI Production Foreman/ Area Supt Attn: Shell Platform "C" HCO 1 BOX 485 Kenai Ak 99611 Shell Western E&P Inc. Q 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, T8N, R13W) for Platform A wells location survey showing the location of Platform C list of conductor/well locations (in relation to the SE corner of Sec. 23, T8N, 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. [f you have any further questions regarding these matters, please continue to contact Susan Brown-Maunder at (907) 263-9613. Very Truly~Yours, W. F. Simpson Manager, Regulatory Affairs Alaska Division WFS/SBBM/vj Enclosures cc' Susan Elsenbast-AOGCC \LETTERS\AOGCC \061190. DOC RECEIVED Alaska Oil & Gas Cons, Anch'orag~ PLATFORM "C" MIDDLE GROUND SHOAL CONDUCTOR/WELL SURFACE LOCATIONS LEG 1 Centered 541.65 ft. No of the SE Corner of Sec CONDUCTOR WELL LEG 2 1 C23-23 2 C32-23 3 C34-26 4 C24-26RD 5 C31-26 6 C34-23 7 C23-26 8 C22-26RD CONDUCTOR LEG 3 LEG 4 9 10 11 12 13 14 15 16 CONDUCTOR 25 26 27 28 29 30 31 32 rth and 1596.41 ft. . 23, T8N, R13W, SM. DISTANCE FROM SE CORNER NORTH WEST 547.10 1599.00 547.25 1594.46 544.25 1591.06 540.57 1590.68 536.91 1593.01 535.88 1597.22 538.03 1600.98 542.18 1602.22 Centered 618.65 ft. North and 1549.76 of the SE Corner of Sec. 23, T8N, R13W WELL DISTANCE FROM SE CORNER NORTH WEST C22-23 623.65 1552.66 C24A-14 624.15 1548.36 C43-14 622.65 1544.76 C41-26 618.25 1543.86 C21-23 613.85 1546.26 C21-26 612.65 1550.46 C24A-23 614.85 1554.26 C13-23 619.].5 1555.66 Centered of the SE ft. SM. 582.42 ft. North and 1489.90 ft. Corner of Sec. 23, T8N, R13W, SM. Centered 505.41 ft. North and 1536.56 ft. of the SE Corner of Sec. 23, T8N, R13W, SM. DISTANCE FROM SE CORNER NORTH WEST WELL 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 C42-23 C31-23 C43-23 C41-23 C33-26 C-LINE C44-14RD C24-23 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 O.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 -0.40 5.90 -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 · L.O~.ATION ~,A.$. PL-ATF~h~H' "C" COOl(, I N I,-E.T ,"'"' AL. ASKA SC~L~ I"2OOD' bilr'Ck Ill47 M EMORAN D'-.¢I State ,.,f Alaska ~.~S CONSERVATION CO~MISSION ALASKA 0IL AzND '~* TO: ,_,onn!e C. S~i DATE: Commissioner FILE NO: April 10, 1990 JT.BF.4690.2 TELEPHONE NO: THRU: SUBJECT.' FROM: Bol~by F o2~'t e~*'"~¢~ Pe cro!eum !ns~ec~or No Flow Test Shell C-42-23 Pl.atfo~n C Middle Ground Shoal Thu~p.J~5_~19__9_q0: I arrived at platform C at 7:15 a.m. and met With Maurlce Dunckley, production supervisor, and Pete HcGrane, production operator. They informed me that the gas lift supply had been closed off the well at ~:00 a.m. and the well was flowed to the test separator which was holding 60 psig on the tubing. Pete and I went to the well at 7:40 a.m. and I checked all valves on the well head and two pen recorder. I requested that the choke be closed on the flow line at this time. The tubing pressure read 60 psig at this time. We then went to the test separator and bled the pressure to 0 psig. At 9:30 a.m., we returned to the separator and checked the pressure. After checking the pressure which was 0 psig, I marked the sight glass and the choke was opened to bleed the pressure of the tubing which had not increased from the 60 psig recorded at 7:40 a.m. We then opened the choke and bled the tubing to 0 psig. i checked the sight glass and it did not show any fluid increase. I checked all the dump lines to insure they were all closed. At 2:00 p.m., we shut the well in and waited until 3:00 p.m. for a pressure build up. At 3:00 p.m. there was no pressure showing on the gauge and i opened a needle valve on the swab valve cap. There was a small amount of gas pressure (3 to 5 psi) at this point. It is my recommendation to the Comanission to accept this well as unable to flow without assistance. Attached to this report are copies of the recorder chart showing casing and tubing pressure and meter reading off the dump lines on the test separator. In summary, I witnessed the no flow test on Shell's C 42 23 well. Attachment 02-001A (Rev. 8/85) .~ //// / ~.,, / , / ; AOGCC SAFETY VALVE TEST REPORT PAGE · PRESSURES - PSIG .6. FIELD: MIDDLE GROUND SHOAL SHELL C PLATFORM OPERATOR: SHELL WESTERN E&P REPRESENTATIVE:K DATE WELL I PERMIT N~iBER I NUMBER I C44-14RDI77-0079-0 C-23-23 168-0030-0 I C.-31-23 [68-0069-0 C-32-23/175d0035-0 G-42-23 ~78-0024-0 I C-43-23'168-00~0-0 C22-26 76-00~5-0 C26-26R1~179-0062-0 C-31-26 167-0063-0 C~36:26 68-0019-0 I I SV TSTIPILOTI FLGI SI DUE I(LOW)I TBG I TBG ~ REMARKS: I I __,1/ SSV IP IFP , ./ ?~ · , SSV TST [__SSSV IIp FP I P 5o · .., I I I I I I I I I I I , I sSSlNI TSTITI. , I_! ~1_1 I_ , , - , · ~ELL NO, G~-'--2'-5-'~ FLOCO FLOCO BID BIH TOTAL.CUT CLEANTOTAL PROD INJ TBG CSG ! i~ATE .... #1 //2 RATE RATE OUT % OIL I CLEAN GAS GAS PSI PS ~-~.. r/~~ ~~/.1 , , ...... [ ~ ~ ~ 7~o ...... tt ,7~~,~ ~ ........ ~ ' D._.'~ ~/~ _ ,~J 0~._ ~/ '~~,r. ~ , ~ ~ "~~~ ~.'~ ..... , ,, . , . . - ' ~4r~P 2~z,o '" ............. /~~~ I ,., ..... _ ~ ~ . , , , ., _' ~' .~ ~ ~ , ........... , .,, ., . . , t . ., _ _ ,.... . ..... - - . . , . " ' , . Il LI Il I i r- ii _ ,i . M EM O RAN Du M TO: THRU: FROM: State of Alaska ALASKA OIL AND GAS CONSERVATION COMMISSION Commissioner Michael T. Minder Sr. Petroleum Engineer OATE: August 8, 1988 FILENO: D.BDF. 008 TELEPHONE NO: SUBJECT~ Safety Valve Tests Shell-MGSU Platform C MGS Oil Pools Bobby D. Fost Petroleum Inspector Thursday, August 4~ 1988: The tests began at 7:30 a.m. and were concluded at 10'-3'0 a.m. With 10 Pilots, 10 SSSV s and 10 SSV's tested. As the attached Safety Valve Test Report shows one SSSV's failed. This will be repaired and the AOGCC Office notified. · , . · -Comment by Mike Minder, Richard Vickerson called August 8, 1988, to notify Commission that the SSSV in C42-23 has been replaced and tested OK. Attachment PilotS Tested 10 Pilots Failed 0 SSSV's Tested 10 SSSVIO Failed 1 SSV's Tested 10 SSV's Failed 0 July 2, 1987 Shell Western E&P Inc. Q 601 West Fifth Avenue · Suite 810 Anchorage, Alaska 99501 State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99502 SUBJECT: SUBMISSION OF REPORT OF SUNDRY WELL OPERATIONS FOR MIDDLE GROUND SHOAL WELL NO. C 42-23 (APPROVAL #6-611) Gentlemen: Enclosed, in duplicate, is the Report of Sundry Well Operations for the perforation performed on Middle Ground Shoal well number C 42-23. If you have any questions, please contact Susan Brown at (907) 263-9613. Ver~ truly yours, /~ D. [;/¥~'sland / Mana~e~ Regulatory Affairs Ala~ Division' SBB/kka Enclosure Alaska OJJ & Gas COILS, SBBF/aogcc. O4b STATE OF ALASKA ALASA,. ,.)IL AND GAS CONSERVATION COMrv,.,~31ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] Perforate L~ Pull tubing Alter Casing [] Other [] 2. Name of Operator 5. Datum elevation (DF or KB) She11 Western E&P I nc. 11 6 ' KB Feet 3. Address 6. Unit or Property name 601 West 5th Avenue, Suite 810, Anchorage, AK 99501 Middle Ground Shoal 4. Location of well at surface Platform C, Leg 4, Conductor 25. 4771'S & 1541'W from NE corner of Sec. 23, T8N, 7. Well number C 42-23 At top of productive interval R13W, S.M. 2611'N & 341'W of surface location At effective depth 2888'N & 385'W of surface location At total depth 2946'N & 400'W of surface location 8. Approval number 6-611 9. APl number 50-- 733-20315-00 10. Pool "G" Pool 11. Present well condition summary Total depth: measured true vertical feet feet Effective depth: measured 9,848 ' true vertical feet feet Casing Length Size Structural Conductor Surface 8,823 ' Intermediate 1,228' Production Liner Perforation depth: measured 9,205 - 9,603' true vertical 8,706 - 9,070' Tubing (size, grade and measured depth) 3-1/2", 9.2#, N-80 ~ 8,628' Packers and SSSV (type and measured depth) packer set at 8,575' 7-5/8", 33.7#, 5-1/2", 17#, Plugs (measured) Junk (measured) Cemented Measured depth True Vertical depth 0-8,823' 8,620-9,848' RECEIVED jUL-~-~ 1-087 Naska 0il & Gas Cons. Commission Anchorage 12. Stimulation or cement squeeze summary Perforate at 8,675' Intervals treated (measured) and 8,679' w/SOS 2-1/8" Enerjet. Treatment description including volumes used and final pressure 13. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 129 59 97 750 70 100 22 164 760 70 14. Attachments Daily Report of Well Operations Copies of Logs and Surveys Run [_J /1.I hereby certif /at the foregoing is true and correct to the best of my knowledge Signed ~ Title Producti on Superi ntendent Form 10-404 Rev. 12-1-85 ~ ~ ~ E' / ,.. ,., .... ,-, I b, Submit in Duplicate DAILY JOB SUMMARY DATE' WELL NO' OPERATION' 12/21/86 C42-23 Perforate GR - GS Perforated 2 test shots at 8,675' and 8,679' w/SOS 2-1/8" Enerjet. First test after perforating was 101 BO + 80 BWPD (cut 44%). Production log will be run to determine if production is crossflowing into GR-GS. RECEIVED JUL.'~' ~ 1987 0il & Gas Cons. SBBF/djs .02a DAILY JOB SUMMARY DATE- WELL NO' OPERATION- 12/23/86 C42-23 Perforate GR - GS Production log to determine loss of approximately 50 BOPD after two test shots in the GR-GS interval. Attempted flowmeter on 7/16" line, but tool failed. Normal cable unavailable. Two attempts were made. Finally ran a pressure/temperature survey on SOS line and found that the well was lifting off the bottom. ,alaska Oil & Gas Cons, Anchorage SBBF/djs.O2a Shell Western E&P Inc. 601 West Fifth Avenue · Suite 810 Anchorage, Alaska 99501 f,.pril 6, 1987 State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99502 Gentlemen' SUBJECT' SUBMISSION OF SUBSEQUENT REPORT OF OPERATIONS FOR MIDDLE GROUND SHOAL WELL C 42-23 Enclosed, in duplicate, is the subsequent report of operations for a recently completed ac'id stimulation on Middle Ground Shoal well C 42-23. If you have any questions regarding this report, please contact Susan Brown at (907) 263-9613. Very truly yours, D. L. Yesland Manager, Regulatory Affairs Alaska Division SBB/kka Enclosures SBBE/SR.4223 STATE OF ALASKA ALASK~ ..~IL AND GAS CONSERVATION COMM, .,ION REPORT OF SUNDRY WELL OPERATIONS V 1. Operations performed' Operation shutdown ~ Stimulate'*-' Plugging '-- Perforate ~ Pull tubing Alter Casing ~ Other Z 2. Name of Operator 5. Datum elevation (DF or KB) Shel 1 Western E&P Inc. 116' RKB Feet 3. Address 6. Unit or Property name 601 West Fifth Ave., Suite 810, Anchorage, AK 99501 Middle Ground Shoal 4. Location of well at surface Platform "C", Leg 4, Conductor 25 4771'S & 1541'W from NE corner section 23, T8N, R13W,SM 7. Well nu~b~_23 At top of productive interval 2611'N & 341'W of surface location At effective depth 2888'N & 385'W of surface location At total depth 2946'N & 400'W of surface location 8. Approval number 7-214 9. APl number 5O-- 733-20315-00 10. Pool "G" Pool 11. Present well condition summary Total depth: measured true vertical feet feet Effective depth: measured true vertical 9,848' feet feet Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size 8823' 7-5/8" 33 7# 1228' 5-1/2" measured 9,205-9,603' true vertical 8706'-9070' Tubing (size, grade and measured depth) 3-1/2" 9.2# N-80 @ 8,628' Packers and SSSV (type and measured depth) packer @ 8575' Plugs (measured) Junk (measured) Cemented Measured depth 0-8823' 8620'-9848' True Vertical depth 12. Stimulation or cement squeeze summary See attached Daily Report of Operations Intervals treated (measured) Treatment description including volumes used and final pressure 13. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 129 59 97 750 100 22 164 760 Tubing Pressure 70 70 14. Attachments Daily Report of Well Operations L~ Copies of Logs and Surveys Run [] 15. I hereby certify that the foregoing is true and correct to the best of my knowledge ~ , ~ _~'f.~r-~ Signed ~/~ -/~ ~-,~ Title Production Superintendent Date ~///'7/~"7' Form 10-404 R 5 Submit in Duplicate DAILY REPORT OF OPERATIONS Well- C 42-23 Date' 04/03/87 Workover' CTU-Acid Stimulation Foreman' T. L. Pritchard 0700-0800 0800-1400 1400-1415 1415-1430 1430-1630 1630-2100 2100 Held safety meetings Rig up ACT and Halliburton Displaced diesel with filtered seawater Pressure test to 5,000 psig RIH @ lO0'/min maintaining 1,000 psig on coil. Tagged 9,700' KB. Circulate HEC @ 1BPM @ 800 psig. Pumped 500 gal of 15% HC1, 1000 gal HF and 500 gal 15% HC1. Displaced acid with 100 bbl filtered seawater. Pumped 15 bbl diesel to help well lift down. Pull out of hole. SBBE/0406 March 19, 1987 Shell Western E&P Inc. Q 601 West Fifth Avenue · Suite 810 Anchorage, Alaska 99501 State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99502 SUBJECT: SUBMITTAL OF APPLICATION FOR SUNDRY APPROVAL FOR MIDDLE GROUND SHOAL WELL NUMBER C 42-23 Gentlemen: Enclosed in triplicate, is an Application for Sundry Approval for an upcoming workover on Middle Ground Shoal well number C 42-23. The coil tubing unit cleanout and perforation is expected to begin sometime around April 3, 1987. If you have any questions regarding this application, contact Susan Brown at (907) 263-9613. Very truly yours, D. [: ~sland / Alaska[/Division ~ Manager Regulatory Affairs SBB/kka Enclosures ECEIVED Gas Cons. Con'~T~issi ~' SBBE/aogcc.4 STATE OF ALASKA ALAS~,,,,~, OIL AND GAS CONSERVATION COMM,,SSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well L] Alter casing II Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order [] Perforate [J Other 2. Name of Operator 5. Datum elevation (DF or KB) Shell Western E&P :[nc. 105' KB feet 3. Address 6. Unit or Property name 601 West Fifth Ave., Suite 810, Anchorage, AK 99501 Middle Ground Shoal 4. Location of well at surfac~latform "C", Leg 4, Conductor 25 4771'S & 1541'W of NE corner of Sec 23, T8N, R13W, SM At top of productive interval 7. Well number C 42-23 8. Permit number 78-24 9. APl number 50-- 733-20315-00 10. Pool "S" Pool 2611'N & 341'W of surface location At effective depth 2888'N & 385'W of surface location At total depth 2946'N & 400'W of surface location 11. Present well condition summary Total depth: measured true vertical feet Plugs (measured) feet Effective depth: measured true vertical 9,848' feet Junk (measured) feet Casing Length Structural Conductor Surface Intermediate 8823' Production 1228' Liner Perforation depth: Size Cemented 7-5/8" 33.7# 5-1/2" 17# J-55 measured 9,205'-9,603' true vertical 8,706' -9,070' 5 intervals Tubing (size, grade and measured depth) 3-1/2", 9.2#, N-80 @ 8,628' Packers and SSSV (type and measured depth) Packer @ 8,575' (8,109' TVD) Measured depth True Vertical depth 0-8823' 86 20- 98 48' R . CEIVED APR 0 Z S87 Oil & Gas Cons. 12.Attachments Description summary of proposal [] Detailed operations program © BOP sketch 13. Estirgated.da4e fqr..~oj'nmencing operation ~pr~ / 5, 1~/ 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 ~¢/_~ ~..~/ Title Production Superintendent Commission Use Only Date ~ -- '~ ~/'"'¢!F7 Conditions of approval Notify commission so representative may witness [] Plug integrity [] BOP Test [] Location clearance Commissioner Approved by IApproval No. by order of the commission Date Form 10-403 Rev 12-1-85 Submit in triplicate PROGNOSIS C42-23 OPERATION: COILED TUBING CLEAN OUT TO REMOVE FILL TO 9680' ACIDIZE HN-HZ. PLACE WELL ON TEST. PERFORATE THE LOWER HALF OF THE HR-HZ ZONE. TUBING: SEE ATTACHED COMPLETION EQUIPMENT DETAIL SHEET PERFORATIONS: SEE ATTACHED COMPLETION EQUIPMENT DETAIL SHEET REFERENCE LOG: DRESSER ATLAS ACOUSTIC CEMENT BOND LOG 6/2/78 ~9~IRED ACID: !000 GALLONS 15% HCL W/ADDITIVES (INHIB,DE) !000 GALLONS 7 1/2%/1 1/2% HCL/HF W/ADDITIVES STATUS: PRODUCING 133 BO + 108 BWPD INJ. 1560 MCFPD 3/5/87 PROCEDURE: !.PRIOR TO CALLING OUT SERVICE COMPANIES, HAVE WIRELINER MAKE A 2.5" DRIFT RUN TO FILL DEPTH. REPORT FILL DEPTH ON MORNING REPORT. CLEAN OUT 2.RU COILED TUBING UNIT AND PUMPING EQUIPMENT. BULLET NOSE WASH NOZZLE IS TO BE SECURED TO 1 1/4" COILED TUBING WITH SWEDGE LOCK OR ALLEN SCREW CONNECTOR. WASH NOZZLE IS NOT TO BE THREADED ON DIRECTLY TO COILED TUBING. TEST ACID FOR STRENGTH BY TITRATION METHOD. PRESSURE TEST ALL SURFACE EQUIPMENT FROM THE PUMP DISCHARGE TO THE WELL HEAD TO 5000 PSI. 3. IF COILED TUBING CONTAINS DIESEL RIH. IF COILED TUBING CONTAINS ANTI-FREEZE DISPLACE ANTIFREEZE WITH FILTERED INJECTION WATER BEFORE RIH. MAINTAIN AT LEAST 1000 PSI ON COIL USING FILTERED INJECTION WATER WHILE RIH. HAVE PRODUCTION OPERATOR PUT WELL IN TEST AND MONITOR THROUGHOUT OPERATION. IF WELL STOPS LIFTING, DISCONTINUE PUMPING AND ALLOW WELL TO UNLOAD. 4. LIGHTLY TAG FILL. WIRELINE FILL DEPTH WAS 9619' ON 2/9/87. WHILE KEEPING WELL LIFTING, BEGIN CIRCULATING OUT FILL USING 5#/1000 GAL HEC MIXED IN FILTERED INJECTION WATER. MINIMUM ACCEPTABLE CLEAN OUT DEPTH IS 9671' REPORTED PBTD IS 9750' IF UNABLE TO CIRCULATE OUT FILL, WASH DEBRIS WITH 500 GALLONS ]5% HCL. AFTER CLEANING OUT FILL, CIRCULATE AN ADDITIONAL HOLE VOLUME (100 BBL) BEFORE GOING TO STEP 5. [ ECEiVED APR O I !997 Oil & Gas Cons. Commls:;'i ACID JOB 5. FILTER ALL FLUID THROUGH 2 MICRON FILTER. IF POSSIBLE, KEEP WELL LIFTING THROUGHOUT OPERATION. WITH END OF COILED TUBING AT 9603' , PUMP 250 GALLONS OF 15% HCL, 1000 GALLONS MUD ACID AND 250 GALLONS 15% HCL. WHEN ACID REACHES EOT SLOW RATE DOWN TO 0.5 BPM AND POH AT 20 FPM TO 9367' MOVE EOT BETWEEN 9603-9367' UNTIL ALL ACID IS PUMPED. POH. 6.PLACE WELL ON TEST. WHEN PRODUCTION STABILIZES AND IF THE CLEAN OUT IN STEP 4 WAS SUCCESSFUL, CALL OUT PERFORATING COMPANY TO CONTINUE OPERATION. PERFORATE LOWER HR-HZ 7. RU PERFORATING COMPANY WITH LUBRICATOR. PRESSURE TEST LUBRICATOR USING !" HIGH PRESSURE LINE FROM OFFSETTING INJECTION WELL TO 2000 PSI. KEEP WELL LIFTING THROUGHOUT OPERATION. PERFORATE THE FOLLOWING INTERVAL BOTTOMS UP 4 JSPF WITH A 2 5/8" HOLLOW CARRIER USING THE REFERENCE LOG: HR-HZ 9601-9669' POH AND RD. 8.PLACE WELL ON TEST. '~ 00'7 Oil & Gas Cons. Corn,... ..... {;OHI'LETION EQUIPMENT DETAIL SIIEET MGS C42-23 3/11/87 NO. ITEM APPROXIMATE TVD. MD. PSI OR 7 8 9 10 12 7 8 9 10 11 12 1. BALI, VAI,VE 2. GAS I, IFT MANDREL #1 3. GAS LIFT MANDREL #2 4. GAS LIFT MANDREL #3 5 GAS LIFT MANDREL #4 6 GAS LIFT MANDREL #5 GAS LIFT MANDREL #6 GAS l, lF'r MANI)REI, #7 GUIBERSON UNI-PACKER VII ()TIS "X" NIPPLE OTIS "X" NIPPLE MUI, E-SIIOE COI,I,AR E.O.T. NOTE: E.O.T. is 9' inside 5 1/2" liner CASING 7 5/8", 33.7#, 0 - 8823' 5 1/2", 17#, 8620 - 9848' PBTD = 9750' TI) = 9848' TUBING 3 1/2", 9.3#, N-80 @ 8629' PERFORATED ZONE IIK--IIN IlK -lin IIK-ItN ItN-ItR ttR-ItZ 300 300 1989 2033 935 3/16 3707 3907 925 3/16 5138 5438 910 3/]6 6272 6628 900 3/16 7180 7596 935 1/4 7862 8314 920 ]/4 8095 8561 955 5/16 8109 8575 8118 8585 8148 8617 8159 8628 8160 8629 8204 8676 GROSS INTERVAL 9196--9215' 9260-9290' 9300-9332' 9367-95O3' 9527-9603' SCHLUMBERGER OFFSHORE SERVICES Shell Western E&P, Inc. A Division of Schlumberger Limited HOUSTON. Tr. XAS 77001 January 27, 1987 601W. Fifth Avenue, Suite 810 Anchorage, AK 99501 A~ention: Mr Joe Fram Iq. WE RI:PLY TO KHLUMBERGIICR oIrp'lHORE II:IIVICEI Kenai, AK 99611 Attention: Shelley Ramsey Gentlemen: Enclosed ore 2 BLprints of the Perf. Rcd. (12/23/86) & Pressure/Temp. Survey (/o~.'23/86) Company SWEPI , Well Middle Ground Shoal "C" #42-23 , Field. -Middle Ground Shoal .,County Kenai State Alaska Additional prints ore being sent to: 1 BL prints, original film Shell Western E&P, Inc. P. O. Box 527 Houston, TX 77001 Attn: Log Files~ WCK 4147 1BL prints, 1 Reverse Folded Sepia State of Alaska Oil & Gas Conservation Commission ~/'3001 Porcupine Drive Anchorage, AK 99501 Attn: H. W. Kugler I BL prin~ Shell Western E&P~ Inc. P O Box c~ Houston, TX 77001 Attn: R. J. Vallejo, WCK 1134 1 BL prints Shell Platform "C" .c/o Shell Kenai Office North Star Route P. O. Box 485 Wik Road Kenai, AK 99611 I BL prints, I Mylar ARCO Alaska, Inc. P. O. Box 100360 Anchorage, AK 99501 Attn: H. F. Blacker prints PLEASE SIGN AND RETURN ONE COPY OF _ THIS TRANSMITTAL. 2 BL nrints, 2 Reverse Rolled Sepia ChevrOn U.S.A., Inc. P. O. Box 107839 Anchorage, AK 99510 Attn: J. L. Weaver prints The film is returned to Shell, Houston. We appreciate the privilege of serving you. RECEIVED BY: DATE: /z/~ Very truly yours, SCHLUMBERGER OFFSHORE SERVICES Roger H. Theis DISTRICT MANAGER December 4, 1986 Shell Western E&P Inc. Q 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- TWO UPCOMING WORKOVERS ON MIDDLE GROUND SHOAL WELL NO.'s C 24-26RD AND C 42-23 Enclosed are two Applications for Sundry Approval for perforations to be performed during upcoming workovers on Middle Ground Shoal (MGS) wells C 24-26 RD and C 42-23. Each application is submitted in triplicate. The estimated date for beginning the work is December 9, 1986. If you have any questions concerning this application, please contact Susan Brown at (907) 263-9613. Very truly yours, for: D. L. Yesland Manager, Regulatory Affairs Alaska Division SBB/kka Enclosures RECEIVED Alaska Oil & Gas Cons. Commission Anchora¢e SBBD/aogcc.5a STATE OF ALASKA ALASK.. OIL AND GAS CONSERVATION COMN_ .SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown E] Re-enter suspended well II Alter casing I I Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order [] Perforate I)~ Other 2. Name of Operator 5. Datum elevation (DF or KB) SHELL WESTERN E&P INC. 105' DF feet 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 "C", Leg 4, Conductor 25. 4771 'S & 1541 'W of NE comer, Section 23, T8N, R13W. 7. Well number C 42-23 At top of productive interval 2611 N & 341 W od surface location At effective depth 2888N & 385 W of surface location At total depth 2946N & 400W of surface location 8. Permit number 78-24 9. APl number 50-- 733-20315-00 10. Pool "G" Pool 11. Present well condition summary Total depth: measured true vertical Effective depth: measured 9,848 true vertical Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size 8823' 7-5/8" 1228', 5-1/2" measured 9205-9603' true vertical 8706-9070' Tubing (size, grade and measured depth) 3-1/2", 9.2#, N-80 @ 8628' Packers and SSSV (type and measured depth) packer @ 8575' feet feet feet feet , 33.7# , 17# Plugs (measured) Junk (measured) Cemented Measured depth True Vertical depth 0-8823' 8620-9848' RECEIVED Alaska 0ii & G3s Cons. C.3mmissi0n 12.Attachments Description summary of proposal ~ Detailed operations program ~ BOP sketch 13. Estimated date for commencing operation Dmcmmbc. r 9, 1986 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 ~'~ ~,~ Title Production Superintendent Commission Use Only Date Conditions of approval Notify commission so representative may witness [] Plug integrity [] BOP Test [] Location clearance Approved by i~i:? ......... '*'*~' ~ ~'~ j Form 10-403 Rev 12-1-85 Commissioner [ ApprovalNo. by order of the commission Date/¢~'-J'-- ~:~ Submit in triplicate HG$ C42-23 STATU$~ Producing 155 BOPD 45% water cut. SCHEMATIC: See attached. PERFORATIONS: ZONE HK-HN (U) HK-HN (M+L) HN-HR (U) HN-HR (L) HR-HZ INTERVAL 9~96 - 9215 9260-9332 :':' 0 1986 9367-9503 ~. ~ ~--~-, 9527-95~5 ~5G5-9~03 Ala~qaOil & NOTE: Place well in test 24 hours before commencing perforating operations. Leave well in test throughout operation. PROCEDURE~ 1. RU slickline and pull SSSV. With slickline make a 2.7" drift run to EOT. POOH and RD. 2. RU service company and pressure test lubricator to 1000 psi using a 1" high pressure line from an adjacent injector wellhead. 3. RU service company to perforate with two shots on a 2-1/8" bar gun with the shots spaced 4' apart. These two charges should be mounted in the center of a 10' perforating strip. Place one weight bar above gun and decentralize with a magnet. This configuration should allow easy movement within the tubing and casing. 4. Choke well back or SI before RIH as deemed necessary by Operations Foreman and RIH. Once the tools are below EOT place well back on full production, It is important that SI time, if any be minimized. 5. With well on test gas lift well until it is operating close to its normal lift depth (normal casing pressure). Normal casing pressure is 775 psi. 6. Perforate GR/GS from 8675' to 8679'. Use cased-hole Gamma Ray- Neutron log ran 6-2-78 for casing collar tie in. 7. Flow well for 1 hour before POOH. While POOH choke well back or SI as deemed necessary. 8. RD service company. 9. Test well for 24 hours taking hourly water cuts and production rates. 10. Production Engineering will consult with Production Foreman to determine if additional testing or perforating is warranted. 11. If additional perforating is warranted, perforate the entire interval by repeating steps 2 thru 8 perforating the zone from 8654'- 8689' 4JSPF with one 35' gun. 12. i Leave well on test for an additional 24 hours. Report stabilized ;,~r.te~t to S. M. Logan (713) 870-4465. , '~," ~Recommended: , _ , Date:_ / ~ ~ C 42-23 Datum 34 ' I tern 1 2 3 4 $ 6 7 8 9 10 11 12 Description Press. Ball Valve ICBM 935t KBM 9251 KBM 910t KBM 900t KBM 935t ICBM 920t KBM 955t Guiberson Unipacker VII Otis X-Nipple Otis X-Nipple 45° Mule-shoe Collar E.O.T. NOTE: E.O.T. is 9 ft. inside 5" liner Size 3/16' 3/16" 3/16" 3/16" 1/4" 1/4" 5/16" Depth 300 2033 3907 5438 6628 7596 8314 8561 8575 8585 8617 8628 8629 TUbilng De ta i 1 283 Joints total 61 Joints 8 rd. 222 Joints Buttress 3 1/2" N-80 9.2~ Casing Detail 7 5/8" 33.71 0-8823' 5 1/2" 17~ 8620-9848' Perforations HK-HN (U) 9205-9215' HK-HN (L) 9265-9275* HN-HR 9367-9503 HR-HZ 9527-9603 HK-HN 9315-9325 10' 10' 136' 76' 10' HK-HN (L) 9332-9325 HK-HN (L) 9315-9305 HK-HN (L) 9305-9295 HK-HN (L) 9295-9285 HK-HN (L) 9285-9275 HK-HN (U) 9205-9196 HK-HN (U) 9196-9205 HK-HN (L) 9275-9315 1 10' 10' 10' 10' 9' 9' 40' *Shot twice [~ 4 holes/ft. I.D. 9-Z48' RE RETAIN THIS SECTION FOR YOUR RECORDS MGS C 42-23 PLS 1 PRINTS 0 NEG. PRINTS NEG. /',, D. I::: r E IV.F- 0 ~__ PRINTS NEG. // (/ i_. ' ' ~, ' ~ ~ PRINTS NEG. ~:~ ~2 -~ .-~-~"~' ~'[~ ~'"'~~.~. PRINTS __ NEG. ~~~~ '"'"':PRINTS NEG. ~ ........... PRINTS NEG. , A..~m ~MII~/O_ NEG. JOHN BOYLE ATTENTION SEPIA SEPIA SEPIA SEPIA SEPIA SEPIA SEPIA SEPIA. SIGNED DATE. 19__ May 31, 1985 Shell Western E&P Inc. 601 West Fifth Avenue · Suite 810 Anchorage, Alaska 99501 State of Alaska Alaska Oil & Gas Conservation Commi s s i on 3001 Porcupine Drive Anchorage, Alaska 99501 Gentlemen' . / Please find the~enclosed Sundry Notices for work that is scheduled to begin around._=~~ ~ 1985., on three of our Middle Ground Shoal wells. The wells are all- on Platform C, C22-26, C34-26, and C42-23. A written approval is requested at your earliest convenience. SBB/ch V/~/.. ltr~~ you rs, Sr. Sta ironmental Engineer Pacific 3ntier Division Enclosure RECEIVED JUN 17 ].§~ __-.---- ,~,laska 0il & 6as Cons. Commission Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator 7. Permit No. Shell Western E &'P l:nc. 78-0024 99501 3. Address 601 West Fifth Avenue, Suite 810; Anchorage, AK 4. Location of Well at surface' Conductor 25, Leg 4. 4771'S & 1541'W of NE corner of Sec. 23, Twsp 8N, Rge 13W. SM 8. APl Number 5o- 133-20315 9. Unit or Lease Name Middle Ground Shoal 10. Well Number C 42-23 11. Field and Pool Middle Ground Shoal 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. _116! KB APL 18756 "G" Pool 12. 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 (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.) 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-I 70). Please see attached prognosis for details of the acid wash. The space~elow for C~mission use correct to the best of my knowledge. TitleSr. Staff Environmental EngineerDate 6.04~85 Conditions of Approf~z, if any: Approved by . Form 10-403 Rev. 7-1-80 ~,pprovee) Copy Returned .~ By Order of COMMISSIONER the Commission Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate N:ID STI~L~TIO~ C42-23 PLATFORJq 'C' #IDDLE 6ROUN~ mi)GL FIELD E;T~TL~: #ell Bas lifting lee RIx), 202 6ross. I, IE~ICAL I~-I'AIL$: ~ee attached sche.~utic. PURPOSE: l~cidize with coiled tubing. 1. Rig up wireline. Test lubricator to 35~ psi. Pull ball valve. Rake drift run to bottom and depth. POOH and rig down. 2. #IRU coiled tubing and acid equipment. Test lines, tr~e and coiled tubinli to 5~ psi. Test hydraulic system and BOP. Test acid compatibility by mixing acid with p~oduced fluid sample and note any fo~uation of sludge. Filter all fluids through a 2 micror, filter. Shut well in. 3. RIH with coiled tubing while pumping 3~ ammonium chloride solution at minimum rate. With coiled tubing stationary 18' above PBTD (or fill depth), pump ~ BBLS of 3~ ammonium chloride solution to fill casing across zone. Follow ammonium chloride with the following t~eat.ent: STAGE FLUID VOLUI~ 1. Xylene Solvent 5~0 gal 2. 1~ HCI 5~ gal 3. 7 I/5 1 1/5 le~2 gal HC1/HF When acid is at the end of the coiled tubing, have coiled tubing located at the bottom perf (96~3'). Pump treatment at 1/4 Bbl per minute. Rake one pass with coiled tubing across interval (9,6~3' -9, 196' ) during each stage of acid t~eatment. 4. Folio- acid with 28 Bbls ~ ammonium chloride. When ammonium chloride is at the end of the coiled tubing have tubing located 18' above PBTD (or fill depth) 5. Place well on production. Pump an additional coiled tubing volume of ammonium chloride to displace ( use diesel if weather or transportation dictate). POOH. I)ltum 34' C 42-~3 l~em ! 1 2 3 4 S 6 7 8 9 10 11 12 I)escrtptton Press. Stze _Depth ii i iii il Ball Valve- KBM KBM KBH KBM KBM KBH Guiberson Unipacker VI! Otis X-Nipple Otis X-Nipple 45° Mule-shoe Collar E.O.T. 93611 3/16' 92511 3/16' 91011 3/16' 90011 3/16' 93511 1/4' 92011 1/4' 95511 5/16' NOTE: E.O.T. ts 9 ft. inside S' liner 3OO 2033 3907 5438 6628 7596 8314 8561 8576 8585 8617 8628 8629 ?ubtn9 Detail 283 ~oints total 61 ~oints 8 rd. 222 ~otnts Buttress 3 1/2' N-80 9.211 Casing Detail 7 5/8' 33.7tl 6 1/2' 17~ 0-8823' 8620-9848' Perforations HK-HN (U) 9205-9215' HK-HN (L) 9265-9275* HN-HR 9367-9503 HR-HZ 9527-9603 HK-HN 9315-9325 10' 10' 136' 76' 10' HK-HN (L) 933~-9325 HK-HN (L) 9315-9305 HK-HN (L) 9305-9295 HK-HN (L) 9295-9285 HK-HN (L) 9285-9275 HK-HN (U) 9205-9196 HK-HN (U) 9196-9205 HK-HN (L) 9275-9315 ! 10' 10' 10' 10' 9' 9' 40' *Shot twice 9, 4 holes/ft. T.D. 9848' Page 83 ti I A I l- Ui- ALA~IqA · ALASKA @J~-AND GA~S GONSERVATION Gr'-~'MISSION SUNDRY riCES AND REPORTb JN WELLS DRILLING WELL[] COMPLETED WELL~[ 2. Name of Operator SHEll OTI_ £OHPAHY 3. Ad,re, ATTN: PRODUCTION SUPERINTENDENT Wayne Simpson, 60] W 5th Ave,, #8]0, Anchorage, AK 9950]' '4. Location of Well Platform C, Leg 4, Conductor 25, 4771'S'&'1541'W of NE Corner, Sec. 23, T8N, R13W SM 5. Elevation in feet (indicate KB, DF, etc.) 105' D.F. 6. Lease Designation and Serial No. ADL 18756 7. Permit No. 78-24 8. APl Number so333-20315-00 9. Unit or Lease Name HGS 10. Well Number C 42-23 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 ~ Altering Casing Stimulate [::::] Abandon [] Stimulation [] Abandonment Repair Well [~ Change Plans r'] Repairs Made [] Other Pull Tubing 1'"] 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 - 12/29/82 12/30/82 Reperforate H.~H~ zone to increase production. Rigged up D/A and reperforated 9300'-9330' (30'). separator. Reperforated 9260'-9290' (30'), Rigged down D/A. seParator.~/~? Tested well through Tested well through 14. I hereby certify that th~ foregoing is true and correct to the best of my knowledge. ,Sign~.~l__. Title Production Administration The $~ace below for Commission use Condilions of Approval, if any; 1/6/83 ( i Approvecl by COMMISSIONER B'¢ Oroer of the Commission Dale Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subse(3uent Reports" in Duplicate SUBMIT IN D', STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE U li l b i fll A L ~ATE* tSee .~th-r st l'uet I(,ns on ii ii i i l WELL cOMPLETION OR RECOMPLETION REPORT AND LOG* i i ,., T¥~, OFW~L:: o,,, ~ .AS ~ ~ WELLL_~ WELL I I ~ DRY[_J Other b. TYPE OF COMPLETION: WEI.I. (IVES b-J EN BACK RESVR. Other 2. NAME OF OPERATOR Shell 0il Company 3. ADDRESS OF OPERATOR 1700 Broadway, Denver, Colorado 80290 4. Loc:.riox o~~ WELL {Report location clearly and in accordance with any State requirements)* at~fa~ Platform C, Leg /+, Conductor 25, /,771' S & 15/+1' W of NE Corner, Section 23-TSN-R13W SN &t top prod. tnterval reported below At total depth 2947' N & 40' W of Surface D.&Tt5 SPUDDED [14. DATE T.D. REa%CHED [15. DATE COMP SUSP OR ABAND. 3- 30-78 [ 5/25/78 } 6/13/78 I [~OTA RY TOO L.q 9850 9306 9763 922/+ uow ~*No Total PRODUCING !NTt~RVAL(S), OF THIS CO~VIPI2gTIOI~T--TO,P, BOTTOM, NAME (MD AND TV'I))' KH-HN- 9205-9332 HR-HZ- 9527-9603 HN-HR- 9367-9503 5. API NU1VLDILICAL C~)DE A.PD 18756 MOS- O' qoo~ "s"~' Section 12, PEI12~,'II'I' NO. 78-24 E2GEVATIONS Il)F, RKB, ItT, GR, eTC)']17. ELEV. CASINGItEAD / 105 ' DF . · INTERVAI,S I)I{~LI.ED BY CABI,E TOOl ,q 0 ,23. WAS D!t{ECTIONAL , F;Ui~VI~Y Yes 24. '175YPE ELECTiIIC AND OTHEA LOGS RUN Gamma Ray Neutron & CBL _k 75. CASING I~ECO1RD (Report 'all strings set in well) CASIf~G SIZE .I,VEI.GHT, LB, FT,~ GI>~ADE I DEPTH SET (MD) 26. LINEX 1R~C ORJ~ 13-3/8 __7-5/8, HOLE SIZE ~ CE/',ILN'i'ING I-IECOtLD ] 7'1 /9 , AD0 ell ft i ' 0. t "A." 9'7/~ 50 sx 0 " TUBING [{EL3 C) i LL) -- AMOUNT PULLED S!Z~J [ TOP (R,iD) [ BOTTOA/I (A~D) [ S~CKS CEM~XT. ..... 1 l',"! t , 28. PERFORATIONS OPEN TO PRODUCTION (iatcrval, size and number) 9205-9196 9275-9325 9367-9433 9483-9503 9527-9603 30. DATE FIRST PILODUCTION [ 6/8/78 } Gas Lifting t27. SIZE '3-i/2 .... DEPTI-I SIqT ( lid ) SET (MD) 8575 A e s " ...... ' ' '" ' - ~ ~1~ ........ '"" dj"' .o. ' ' ' I .....~-'"Pvoducing DATE OF TEST, OII~---BBL. GAS--RICF. WF/I'ER--IIIDL. (_;x\S-OII~ iI.%TIO 8/18/78 2/+ ~ J 28/6/4 [r~zs'r =gv I Tv, I xo6 I 30 FLOW, TUBING ~I~¢G'3RL~'~UItE |CALC~TEI) OIL~BbL. GAS--AICF. WA'rEIt--BBL. JOIL GILiVITY-A:PI (CORR.) 124-HOUR RATEJ :r~P'~ssi0 0 760 I > - I ' I I3t.8 ~1- DISPOSITION OF GAS (80gal, used lei/ual, vented, etc.) .... TE~MT \\' I'['NESSED BY Injected 82. LIST 014' ATTACHMENTS _ Directional Survey/q (Logs & Cementing Details previously forwarded) 33. I hereby Certify ihat.t, he fed%doing and attached information is ~mplete and correct as determ'lned from all-ava'ilable . SZO~E~ ~~ Sr. gngr. Tach. _ ......... TITLE I - *(See Instructions and Spaces for Additional Data on Reverse Side) INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on. ell types of lan.:Js end leases in Alaska. Item: 16: Indicate which elevation' is used as reference (where not otherwise shown) for depth measure- mentsgiven in ether spaces on this form and in any attachments. Items 20, and 22:: If this well is completed for separatc production from more than one ~nterval zone (multiple completion), so state in item 20, and in item 22 show the plcduciag interval, or intervals, top(s), bottom(s) and name (s) (if any) for only the interval reported in item 30. Submit a separa!e report (page) on this form, adequately identified, for each additional interval to be sepe'~ately produced'J, sho'w- lng the additional data pertinent to such interval. Item26: "Sacks C~ment": ':~ttached supplemental records for this well should show the details of any mul- tiple stage cementi'~g and the location of the cementing tool. Item 28: Submit a'"separate completion report on this form for each interval to be separately produced. (See instruction for items 20 and .22 above). ~4. SUMM'AR'Y '6F FOJIMATION TESTS INCLUDIN(; INT'EFLVAI~ TESTED, PRE.~U~E DAT~ ~~OV~RI~ OF OIL, GAS. ~. G~GiC WAT~ AND MUD ~ NA~ , ,, HO 890 ~ 8421 No DST~s ~ 8966 8483 ~ ; HE 9034 8547 ~ 9069 8598 HI 9134 8640 ~ 9189 8690 ~ 9340 8830 ~ 9505 8983 HZ 9676 9224 ~6. CO~E DATA, AqTAClt BRIE~ ~C~'~ONS O~ LIT~OLOGY. ~OROSITY. FRA~. ~~ AN~ D~q'ED NI~OWS OM OiL. GAS OR WA~. No Cores' rLATF'~r4~I C PPOI) I.E~ ~ CIIH,h $'~[LL ~l;Cq ~TANI)~RD rIDDLE GRr~LIII..~ SHIjAL FIELI) ~5 -lSql (Pz~I~IU8 tIF C,}nVATIJR£ ~PPP']ACH) DE$('RI PT lO:'l i'EASUPLD SUB8I- A t'lr I',TERE.~T hEPTH i.~El' 1"~ T~,IF.. VF. Pl ICAL unO~~ ~&OOO -3699,.~ ~79u 70oo 7000 -6512,3 ~1 ? Hr 905') -~a93, I .<~ 5'~~ ~I ')130 -aSSa.7 O~TD u7o3 -gll~.b ~'~ ,! .8 .0 .I .? ,6 ,1 .1 UF 1 OF OIJTpIIT PR I F' T DE(; '11,4 ~1 57 ~5 58 I7 %a 17 ~a 1~ ~n ~0 ~ 71 $1 17 %0 CONFI',m~ INPUT THICKNE,~ C[}~PE C T ! t. ATERAL DEFLECT TO!'I 8(,,) E n~, t:'(-] ClIORI) ! I,Ia TE8 x ,997 12,0 '3o,0 -a750,0 -15n2.o .gla 62a,0 -75.0 -~llU7.0 -lh16,0 ,gO5 1022,0 -173,0 -37~q,0 -171a,0 ,oho i3RP,O -2~2,0 -338~,U -17gt,O ,951 1678,0 -313,0 -3093.o -lflqu,o ,o/t7 2o13,o -3q~,o -R7Sg,O -laSO,O ,o~ 2329,0 -3aP,O -~aq2,0 -1883,0 ,o53 2bll,n -3/tl,O -2160.,) ,~ua 25~.o -~,0 -~1~.0 -l~a~.O · 922 2712.o -352,0 -2nbq,O -18o{,u .9Pq 2788,o -~81,0 -~003,0 -190~,0 ,9~n ~9,U -373,n -19~2,0 -IQIU.O .93a 2aoO.O -3fl8.0 -I~81,0 -1q27,0 ,oa3 291q,n -3~3,0 -1852,,) -193u,U D I J~ECT 1Ut'!AL II~FUPUATION IIHIT3 OF niITPUT CUNFOP,,1 I:~!PIIT Om:LEO Ir,, DEr.;PEE$ PEP D A T A D E ~ ! V F. I') F ~ 0 ~ ~ E A B U P ~ I~. E tJ T $ VEPTICnL LA'IF. PAL PEFLr. CT Irai nnG SUi~Vf: Y POlUT DE. PT. F~O~; SURFACE LnCATItlll LEa CrlflPl)llV~lE,~ t~DF) ,~ r)a 8¢-) F. OR '4(-) Y x 0 0 O 3~0 1 1~ $ 19 E ]bu.n So7 ~27 .$~ ~ 0 S 7a E dSI.g :102 2 0 f~ 89 E a91.9 51~ 1 0 ~' G~ E 517.~ 5q~ ~ o H 70 E 5u7,~ ~7~ ~ t{~ N ~15 E ~77.8 630 q n N al E ~3R.7 671 ~ 0 N 6] E h70.6 7~1 5 '1~ I'~ bn E 7.~0.3 ~P~ 1075 ] ~5 IJ Ge ~J 1072.9 11"5 ,~ 3n "; ~5 E 11~.7 1210 5 15 ~ 21 E 1207.5 ~33~ l~,]n ~1 n ~ 1~l "~ 1~.~ 1720 !~77 8! ~{~ rj 11 ,{ l~U'J.7 ~3u~ Pl I~ r,: la .'{ ~27A.1 ~/:n5 2'l ') · 0 ,0 .o -,q771,0 - 15'J l ,0 -3,7 I ,3 ,3 ,a77a.7 -153g.7 -~1,6 I ,7 1 ,q -~775,6 - 153q, 3 -6~0 u, 1 2.a -a777.0 -1536,q -~, 1 5,~ /~,~ -q777, I -1535.n -6.0 0.3 S,q -a777,0 -153q,7 -5.8 7.0 3.5 -a776.8 -15.~.0 -5, I 8, I d,3 -a776. I -1532.9 -3,q ~. 1 3. -,8 I2.a ~,~ -a771,8 -tSPa,b 1 ,~ 17,5 9.2 ~1 ,P. 15.~ ~5.3 .~ -075~,~ -1qo5,7 !7.8 ~°.7 1 ~2. ! 53,0 37.7 52.3 /J.O -tj733,3 -lOnO.7 ,~6.o 37.b 117,q 3o.r: ~,a -liA53,5 -l~ll.O i ~1~.5 23,5 I .$ -/J~J/J .5 -1517.5 ?03, ~ 12.5 .~ -;~5~7.7 -152~.5 ~1~.3 -22.2 3~, 2 .~7. ~ d:~q, 2 -38.7 ,a -~1~21 .~ -157o,7 7lA,L% -u6.P .] -,?(,%,{, 7 -15~7.~ ~'~(',~ -1J7.$ .7 -3~).7 -1.~78.~ ') Id..% . t g~ .V . ,I .~70~. 1n~7.7 -1~1.5 1.P -~7J3.3 -I 7J~.S I lrg," -l'~,q I { lol,n -?Cb.F l.,a -'.~l",(' -17~17.5 2,1 l,t ,t ,3 · t{ 3,/4 1,1 ,7 o! .5 ,5 ,1 ,t · ti ,7 e5 et 3.7 .? -3577.1 -3539,3 -Ja31.7 -3313.1 -313o.6 -305().6 -301~.3 -~t3,~ -~623.u -2~3b .8 -7169.1 -~Oq7,0 -iqOb,7 -I~h9,7 -tS~3,v -1753,h =17~1.3 -1773,3 -178a.1 -lTqS,tl -1~08.8 -1~3o,q -18a7.1 -1~50,0 -l~5].b -1R50o0 -18a~,q -18ub.~ -1855,5 -IR58.0 -16t$,0 -l~O,a -1~3,o -!R~8,0 -lSob.u -lq39,5 1700 Bray ~ ~, Colorado 80202 ~ t~%~ revi~ the file on Shell's ~ddle ~ Shoal $C4223 w~ll and find that our last z~ c~1 this w~_ll was for the month of June, whidl ~ subsequently received c~ m~ 28, 1978. Sinoe this w~ll now appears to be pzoducing regularly, can we assum~ that it is ccmpleted ~ a ccmple~ report is du~? Please ch~ck your files ~, if ~ w~ll is oc~p_~~, please forward ~ necessary f~ at ~ ear.st cc~~ce. Very truly yours, DRESSER ATLAS DIVISION, DRESSER INDUSTRIES, INC. P.O. BOX 1407,.HOUSTON, TEXAS 77001 713 784-6011 TWX 910-1381-3;08 August 28, 1978 State of Alaska Division of Oil and Gas Attn: O.K. Gilbreath, jr. 3001 l~orcupine Drive Anchorage, Alaska 09501 Dear Sir: Enclosed please Re.: Transmittal of Data Shell Oil Company ( Final l~rints ) HCC 999 .. find the data as described below: h~2LL NAME AND LOCATION DATA Shell Oil Company M.G.S. C-44-14'RD Middle Grounds Shoals Kenai, Alaska , Shell Oil .C ompan~. Middle Ground Shoal Kenai, A[aska 2 pr ints 1 Sepia l~rints Sepia OiVi~/o# Oi 0ii and Oas Conservation Anchorag~ Please acknowledge receipt of attached copy of this letter. the information by signing and Very truly yours, returning the Olin R. Holt Manager Log Analysis Dresser Center Center RECEIVED BY S H ELL OIL COMPANY 1700 I] ROADWAY DENVER, COLORADO 80202 July 13, 1978 Subject: Shell-ARCO-Standard Middle Ground Shoal Mr. O. K. Gilbreth, Jr. State of Alaska Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Gilbreth: Attached are two copies of the Monthly Report of Operations for June, 1978. KWL:ts Yours very truly, For: R. Planty Division Operations Engineer Rocky Mountain Operations Office Attachments cc w/Attach: Atlantic Richfield Company Standard Oil Company Amoco USGS Form No. REV. 3-1-70 SUBMIT IN DUPLICATE STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS $. APl NUMERICAL CODE 50-133-20315 6. LEASE DESIGNATION AND SERIAL NO. APD 18756 1. 7. IF INDIAN'ALOTTEE OR TRIBE NAME WELL WELL OTHER 2. NAME OF OPERATOR 8. UNIT FARM OR LEASE NAME Shell Oil Company Middle Ground Shoal 3. ADDRESS OF OPERATOR 9. WELL NO. 1700 Broadway, Denver, Colorado 80290 C-42-23 4. LOCATIONOFWELL Platform C, Leg 4, Conductor 25: 4771' S & 1541' W of NE Corner of Section 23-T8N-R13W, S.M. 10. FIELD AND POOL, OR WIL~AT Middle Ground Shoal 11. SEC. T. R. M. (BOTTOM HOLE OBJECTIVE) Section 23-T8N-R13W, S.M. 12. PERMIT NO. 78-24 13. REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED, PERFORATIONS, TESTS AND RESULTS FISHING JOBS JUNK IN HOLE AND SIDE-TRACKED HOLE AND ANY OTHER SIGNIFICANT CHANGES IN HOLE CONDITIONS. OPERATIONS FOR JUNE 1978 Recemented liner @ 9848 w/150 sx Class "G". Tested to 2000 psi, ok. Ran logs. Ran prod equip. Presently production testing. SIGNED TITLE Div. Opers. Engr. DATE 7/13/78 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 oil and gas conservation committee by the 15th of the succeeding month,unless otherwise directed. S H ELL OIL COMPANY 1700 B ROADWAY DENVER, COLORADO 802.02 June 6, 1978 Subject: Shell-ARCO-Standard Middle Ground Shoal Mr. O. K. Gilbreth, Jr. State of Alaska Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Gilbreth: Attached are two copies of the Monthly Report of Operations for May, 1978. KWL:ts Yours very / Division Operations Engineer Rocky Mountain Operations Attachments cc w/Attach: Atlantic Richfield Company Standard Oil Company Amoco USGS Form No. P-4 REV. 3-1-70 SUBMIT IN DUPLICATE STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS $. APl NUMERICAL CODE 50-133-20315 6. LEASE DESIGNATION AND SERIAL NO. APD 18756 1. 7. IF INDIAN'ALOTTEE OR TRIBE NAME WELL WELL OTHER 2. NAME OF OPERATOR 8. UNIT FARM OR LEASE NAME Shell Oil Company Middle Ground Shoal 3. ADDRESS OF OPERATOR 9. WELL NO. 1700 Broadway, Denver, Colorado 80290 C-42-23 4. LOCATION OF WELL Platform C, Leg 4, Conductor 25: Corner of Section 23-T8N-R13W, SM 4771'S & 1541'W of NE 10. FIELD AND POOL, OR WILDCAT Middle Ground Shoal 11. SEC. T. R. M. (BOTTOM HOLE OBJECTIVE) Section 23-T8N-R13W - SM 12. PERMIT NO. 78-24 13. REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED, PERFORATIONS, TESTS AND RESULTS FISHING JOBS JUNK IN HOLE AND SIDE-TRACKED HOLE AND ANY OTHER SIGNIFICANT CHANGES IN HOLE CONDITIONS. OPERATIONS FOR MAY 1978 Drilled to 8832' Ran 7-5/8" csg to 8823 & cmt'd w/450 sx Class "G" w/additives Lost DP. Fished & recovered same. Ran logs Cmt'd 5-1/2" liner @ 9848 w/210 sx Class "G" w/additives Presently recmt'g liner 14. I hereby certif~.t the~j~~ect SIGNED ~ '= ' U TITLE Div, 0pers. Engr. DATE 6/6 /78 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 oil and gas conservation committee by the 15th of the succeeding month,unless otherwise directed. Form 10-403 REV. 1-10-73 Submit '~lntentlons" In Triplicate & "Subsequent Reports" In Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) 1. [ GAS r'-] g~--~L WELL OTHER ~ NAME OF OPERATOR Shell 0il Company 3. ADDRESS OF OPERATOR 1700 Broadway, Denver, Colorado 80290 4. LOCATION OF WELL At surface Platform C, Leg 4, Conductor 25: 4771' S & 1541'W of NE Corner of Section 23-T8N-R13W, SM 13. ELEVATIONS (Show whether DF, rT, GR, etc.) 105 ' DF 14. Check Appropriate Box To Indicate Nature of Notice, Re 5. APl NUMERICAL CODE 50-133-20315 6. LEASE DESIGNATION AND SERIAL NO. APD 18756 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Middle Ground Shoal 9. WELL NO. C-42-23 10. FIELD AND POOL, OR WILDCAT Middle Ground Shoal 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Section ?3-T8N-R13W - SM 12. PERMIT NO. 78 -24 ~ort, or Other Data NOTICE Of INTENTION TO: TEST WATER SHUT-OFF [~ PULL OR ALTER CASING FRACTURE TREAT ~ MULTIPLE COMPLETE SHOOT OR ACIDIZE ABANDON* REPAIR WELL CHANGE PLANS (Other) Complet:ion Prognos is SUBSEQUENT REPORT OF: FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. See attachment SIGNED . _ TITLE (This space for State office use) CONDITIONS OF APPR6VAL, IF ANY: ,~ Div. 0pers. Mnsr. Petroleum Engneer See Instructions On Reverse Side DATE 6/6/78 June 13, 19 78 DATE Approved Copy Returned COMPLETION AND TESTING PROGNOSIS SAS MGS C-42-23 MIDDLE GROUND SHOAL FIELD, ALASKA Status · .i 5-1/2" 17# N-80 Hydril SFJ casing has been run and cemented as a liner from total depth +_9,800' MD to -+8,600' MD (overlap of _+200' inside 7-5/8" production casing). · Cement has been cleaned-out and 5-1/2" liner has been scraped to PBTD -+9,720' MD. Liner lap has been pressure tested with clear water. Any necessary squeeze work as a result of the pressure testing has been accomplished. A pack off has been installed on top of the liner. ~ Hole standing full of clear water with 8.7 ppg completion fluid(KC1 water) i_9_n liner. Objectives · Obtain cement bond/correlation log · Spot completion fluid on bottom (if not previously spotted) · Run production eqUipment · Perforate wel 1 · Acidize (if warranted) and · Place on gas lift production Procedure 1. Rig up Dresser Atlas and run Acoustic Cement Bond Log with Acoustic Signature curve (not variable amplitude density display), gamma ray and Casing collar log from PBTD to above top of cement (bonding) in 7-5/8" production casing (log up into "free ringing pipe"). a. Run log with pressure on casing to compensate for clear water inside casing, i.e., wellhead pressure = (mud grad. - wtr. grad.) X (TVD). b. Repeat log with an additional 1000 psi over pressure used in Step 1.a. c. Squeeze work may be necessary based on results of Steps 1.a. and 1.b. Operations Engineering will recommend cement composition and squeezing procedures if required. SAS MGS C-42-23 2 2. On same Dresser Atlas set-up, run gamma ray/neutron/collar log from PBTD to cement top outside 7-5/8" (as established by CBL in Step 1) then continue gamma ray/collar log up to _+5,000 MD. Rig down Dresser Atlas. 3. If completion fluid has not been spotted previously, run in hole open-ended (with bit if CBL wireline measurements indicate fill into planned perforated ~interval); otherwise, proceed to Step 4. a. If fill is indicated, reverse circulate out to PBTD. b. Otherwise spot 26-Bbl. 8.7 ppg completion fluid "pill" from PBTD to packer setting depth, emplOying conventional circulation. c. Mix KC1 with fresh water, not injection water, to a density of 8..,7 ppg. ., 4. Run production equipment in accordance with separate "Completion Equipment Detail" sheet. 5. With packer in'7-5/8" casing at _+8,575' MD (tail pipe must extend down into top of liner), mark tubing for landing and pressure test the ball valve hydraulic line. Pull up and space out for landing (allow two feet for slack off after setting the packer). Lower the tubing back to packer setting depth. -6. Pressure the tubing to 1500 psi and set the packer; raise the pressure to 2500 psi and hold for 15 minutes. Pull equalizing prong from X-Plug. Pull X-Plug. 7. Install back pressure valve in tubing hanger and close the ball valve. Nipple down BOPE and riser. Nipple up Xmas tree and pressure test to 3500 psi. Remove BPV and open ball valve. 8. Gas lift water from well down to bottom:GLV leaving about 1,200' of water (pressure head) above intended initial perforations. Monitor volumes of fluid lifted to assure well cleared to bottom valve. 9. Rig up Dresser Atlas with lubricator and grease injection head; pressure test to 3000- psi. SAS MGS C-42-23 10. Perforate selected intervals (perforation intervals will be coordinated through J. R. Jord.e.n. and D. Cushman) with 4 holes per foot using' a. 2.6" Slim Kone steel, hollow carrier gun loaded with b. 12.5 gm Jumbo Jet charges (zero-phased) and c. Position with magnet at bottom of gun assembly. d. Perforation depths will be referenced to open-hole logs via CBL/GR/ collar locator log; report open-hole log (DIL-LL8) depths. ll. Produce (GL) well between gun runs. ~ ~ 12. Release rig after perforating has been completed. 13. Maintain surveillance of production kind and rates (fluid cuts, gauges, pressures, injection rates, gravities, etc.) throughout perforating operations. 14. Test well long' enoUgh to establish fluid composition and rate before opening next zone (ioe., HR/HZ, HN/HR, etc.). 15. After perforating is complete, establish "official" completion rate. A supplemental prognosis covering multi-rate testing is anticipated. E. D. Manly'JC COMPLETION EQUIPMENT DETAIL SAS MGS C-42-23 ITEM · Tubing hanger . Ball valve · GL Mandrel #1 (KBM) · GL Mandrel #2 (KBM) · GL Mandrel #3 (KBM) · GL Mandrel #4 (KBM) · GL Mandrel #5 (KBM) · GL Mandrel #6 (KBM) · GL Mandrel #7 (KBM) . Packer (7-5/8" Guiberson Uni-packer VII)* · Landing Nipple (Otis Type X) · Joint of tubing · Landing Nipple (Otis Type X)** TVD 2000 3700 5125 6275 7175 7850 8104 MD 40' 300' 2044' 3896 5423 6638 75.,88 8301 8568 8575' 8585' 8625' *Set as close to liner top as'practical in order that deepest GL Mandrel can be at proper depth and that end of tubin9 extends into 5-1/2" liner. **Run with Plug and Equalizing Prong seated in Nipple to facilitate setting packer. (Tubing- 3-1/2", 9.2#, N-80, Buttress, special clearance couplings) GAS LIFT DESIGN (BY T. C. ODOM) MANDREL MD TVD VALVE TYPE SET PRESSURE #1 2044' 2000' BK #2 3896' 3700' BK #3 5423' 5125' BK #4 6638' 6275' BK #5 7588' 7175' BK #6 8301' 7850' BK · #7 8568' 8104' BK PORT SIZE 935 3/16" 925 3/16" 910 3/16" 90O 3/16" 935 1/4" 920 1/4" 955 5/16" SHELL OIL COMPANY 1700 B ROADWAY DENVER, COLORADO 802.02 May 3, 1978 State of Alaska Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99501 Attention Mr. O. K. Gilbreth Gentlemen: Attached are the following documents per your discussions with Mr. M. L. Woodson: 1. Monthly Report (March 1978) - -~ - 2. Monthly Report (April 1978) ~~ 3. Monthly Report (April 1978) 4. Sundry Notice - A-23-1 5. Directional Surveys - A-31-14, A-12-1 and C-44-14 The well logs for A-31-14, A-12-1 and C-44-14 will be sent to you shortly under separate cover from our Houston Office. TB:ts prs y R. Planty Division Operations Engineer Rocky Mountain Operations Office At tachments cc: Mr. M. L. Woodson Fm-m ~o. P-.-4 REV. STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUBMIT IN DUPLICATE MONTHLY RE:PORT OF DRILLING AND WORKOVER OPERATIONS WELL WI;LL NAME OF OPERATOR Shell Oil Company 3. A'bDRESS OF OPEP. ATOR 1700 Broadway, Denver, Colorado 80290 4. LOCATION OF w~LL Platform C, Leg 4, Conductor 25 - 4771' NE Corner of Section 23-T8N-R13W, SM S & 1541' W of API NUi~IERiCAL CODE 50-133-20315 LEASE DESiGI~AT'ION AND SERIAL NO. APD 18756 IF INDIA],~, ALOTY'EE OR TRIBE NAME 8. L.~IT F.~'~t/l OR LEASE lqAME Middle Ground Shoal g WELL NO C-42-23 10 FIF~DANDPOOL. OHWILDCAT Middle Ground Shoal-"G" Pool 11 SEC. T., R.. M. (BOTTOM HOLE Se~ z~n~3-T8N-R13W, SM 12. PERIVIIT NO 78 -24 13. REPORT TOTAL DEPTH AT E.ND OF MONTH. CHA.NGF-,S IN HOLE SIZE, CASING AN'D C:":":":":":":":":":~M~i~NG JOBS INCLUDING DEPTI-I SET AND VOLUIVIES USED. PEItFORATIONSi 'I-ESTS ~ HESULTS FISHING JOB~ JU%-i~K LNI HOL~E AND SIDE-TI:~ACKED HOLE AND AaN'Y O'I'H~R SIGNIFICANT CH.A. NG~S IN HOL~ CONDITIONS OPERATIONS FOR APRIL 1978 1. Drilled 17-1/2" hole to 2580'. 2. Ran and cemented 2580' 13-3/8" 61# & 54.5# K55 BTC csg w/1200 sx Class "G" w/2-1/2% prehydrated gel and 2% CaC12. Tailed in w/300 sx Class "G" + 2% CaC12. 3. Nippled up BOP's & tested to 3000 psi & hydril to 1500 psi. Witnessed by Mr. R. Douglas ' 4. Drilled 9-7/8" hole to 7863'. STATUS: 4/30/78 - Tripping @ 7863' 14. I hereby certify p,..., he freer *' 5/3/78 smmm u .... _ ~ ~ Div. 0pers. gngr ........... NOTE--Report on this form is requTred for each calendar ~nth~ regardless of the status of operations, and must ~ filed in duplicate wifh tae oil and gas conservation commifee bythe 15~ of the succNdiflg mon~,ufll~ otherwise directed, Form ~o. P-.-4 ~/'. 5- 1-70 STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. SUBMIT IN DI/P. LICATE 1700 Broadway, Denver, Colorado 80290 API NL~{ERiCAL CODE 50-133-20315 LEASE DESIGNATION AND SERIAL NO. APD 18756 ? IF INDI^RT, ALOT/-EE Ol{ TRIBE FLAME NAME OF OPI~ATOR 8. L~IT FAI~I OR LEASE NAME Shell 0il Company Middle Ground Shoal ADDRESS OF OPER,A'rOR 9 WEI~L NO C-42-23 4. LOCA~ON &F WEJ~L Platform C, Leg 4, Conductor 25 - 4771' NE Corner of Section 23-T8N-R13W, SM S & 1541' W of l0 s~Lo ^_-~D ~OOL, oR WrLOCAZ Middle Ground Shoal-"G" Pool =~i S~C, T., R., M. C~O~OM HOLE Section 23-T8N-R13W, SM 12. PF2RMIT NO 7~-24 13. REPORT TOTAL DEI~TH ATEkND OF MONTH, CI-L~NGES IN HOLE SIZE, CASING A~ C~F~TI}~G JOBS INCLI;DING DEPTH SET ~ VOL~ USED~ P~O~TIONS. ~TS ~ ~SULTS FISHING JO~ J~K LN HOL~ AND SIDE-TRACKED HOLE ~D ~Y O~R SIGNIFIC~T ~~ ~ HO~ CO~ITIONS OPERATIONS FOR MARCH 1978 1. Spudded well 12:30 p.m. 3/30/78 2. Drilled 17-1/2" hole to 727' STATUS: 3/31/78 - Dyna drilling @ 727' ,'~ L'hora ]0 ers ~ r 5/3/78 NOT~--Reaort o f il G'uired for tQCh coltndor ~ntht regardlell~f the ltOtuS of operations, and ~;st ~ filed in duplicate with the oil and gas conservation commiflee by the 15~ of the suec~4ing mon~. u~le~ Ofherwila direcfa4. Russell A. Doug~ss Petroleum Engineer DEPAR~4ENT OF ~kTURAL RESO~q Division of Oil and Gas April 19, 1978 Witness ROPE. testing Shell C42-23 Thurs~.~Q_Ap~.ri.,1 13, 1978: Talked with Larry Hillegeist, Shell drilling supervisor on ~/nesday. He inf~ r~ that they were cementing surface casing and wc~tld p~ly be ready to test BOPE this morning. I traveled to ~ via AAI and caught the 8:30 AM chopper to the 'C' platfo~n. I ~t with Larry at 9:00 A.M. He info~ me they had dc~e a top job last night but would still be ready to test BOPE sc~et/me today..Their 13 3/8" casing was set at 2578'. Started testing at 10:30 A.M. _~=st was con~ %~ith water and pressure from the platfozm ~ter injection system which provides 3400 PSI. First test with the plug in the hole and the pipe rams closed proceeded frcm there to test the inside and ~ide wing valves on the choke and kill lines The top vms then put on the choke in order to test the kill line back to the pump. One of the'~ type connecti~ leaked and while they w~re changing it out Larry and I inspected the accu~lator rock. t~h~lril pressure was 1000 PSIG and acc~nulator pressure was 2850 PSIG. The pump was kicking cm excessively indicating a leak sc~ewhere in the systsm. The nitrog~. ~n backup ~H~ ccn~ four bottles all charged to 2200 PSIG. At this point we broke for lunch since they ~ still f'Lxing the After lunch we tested the choke rmm~ifold. Chok~ manifold c~nsisted of seven valves, thirteen flanges and t~o n~~3.y adjustable chokes. All valves and flanges tested to 3000 PSIG. Tested Hydril to 1500 PSIG, pulled out of the plug and tested the blind rams to 3000 PSIG. By this ~ the union in the kill 1/ne was back together and %~ tested. this line to 3000 PSIG. Reassembled the check valve and tested it to 3000 PSIG. ~ then picked up the kelly and we tested the ~ kelly valve and kelly-oock to 3000 PSIG. Test was ccmpleted at 3:00 P.M. La/=~ and I talked briefly about the accumulator. He had located a repla~ for t%~ ~ valve, which was leak~ and said he could have it installed before drilling out the shoe. Sinoe this ~uld not affect ~ng in the well I did not make any stipulations c~n~g the repla~t~ but ~ did agree it was in the best interests to replace I c~r~leted a field inspecticm report and gave a copy %0 Larry and a copy_ is attached. In ~: I witnessed BOPE testing, for Shell C42-23. One leak ~as ~ a~ repaired. All other aspects of the test were satisfactory. . !: : :i']~: '.';' . Ai~!¢~611~1 and Gas Conservation Commi~ ' . · ~' · ~:-~_ .-:. ~'Field Inspection RePort ~ . ~ [ Drlg. permit NO,~-2~/ '~ ~/~R/~¥ ~]~Platfm Sec25 T~A/ R ~3~ ~M ~ ~_": Operator ~'/-/~'"KL 'Represented by~-h,t.~-~/,~-:r' Name & Number ~' ~/.~-,.~.3 .... ~ Satisfactory Type Inspection . Satisfactory Type Inspection ; ~: Yes No Item~( ) Location,General Yes No Item (~ BOPE Tests 1. Well Sign 2. General Housekeeping 2.- Reserve Pit-( )open( )filled 4. Rig ( ) Safety Valve Tests 5. Surface-NO. Wells 6. Subsurface-No. Wells ( ) Well Test Data 7. Well Nos. , , , 8. Hrs. obser , ',~. , 9. BS&W -. 10. Gr. Bbls. ~ , , , ( ) Final Abandonment 15./~:~"Casin.q set @~$78' 16. TesC fluid-(~)wtr.--~-~ )mud ( ) oil 17. Master Hyd. Control Sys.-,~liS'~ psig 18. N2 btls.m~o~ ~. psig 19. Remote C~ntrols 20. Drilling spool- "outlets 21. Kill Li.ne-(~2/ Check valve 22. Choke Flowline ( ) HCR valve 23. Choke Manifold No. va~vs ~flgs/~ 24. Chokes-( )Remote( )Pos.(~-~dj. 25. Test Plu~-(~)~ellhd( )csg( )none 26. Annular Preventer,/_J'mo?si.e 27. Blind Rams,~aoapsi~ ( ) ( )- 11. P&A Marker (,)/~. ( ) 28. Pipe Rams joo~ psiq ( ) ( ) 12. Water well-( )capped( )plugged (.~)~ ( ) 29. Kelly & Kelly-cock ~oo~3oo__?~_9_psig ( ) ( ) 13. Clean-up (~)/~ ( ) 30. Lower Kelly valve ~o p~si~ ( ) (') 14. Pad leveled ~ (-~)~ ( ) 31~__.Sa~ety Floor valves-~-(-~V '(~Dart Total inspection observation time_Z-/ (h~days Total numben~leak~and/or equip, failures ~ ~ Remarks ~o~r9 7"~',~T ~o~ /w]/~/~/e /~ d,~n-~-~--?~'oz~Z~,~ ~ Z~,~- ~,_~ cc' Notify in days or when ready Inspected by ~, Z~2~Date%~_3/Tg' Form No. REV. 3-1-70 SUBMIT IN DUPLICATE STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. WELL WELL OTHER 2. NAMEOFOPERATOR Shell Oil Company 3. ADDRESS OF OPERATOR 1700 Broadway, Denver, Colorado 80290 4. LOCATION OF WELL Platform C, Leg 4, Conductor 25:4771'5 & 1541'W of NE Corner of Section 23-T8N-R13W, SM 5. AP1 NUMERICAL CODE LEASE DESIGNATION AND SERIAL 8.UNIT FARM OR LEASE NAME Middle Ground ..~ 9. WELL NO. C-42-23 lO. FIELD AND POOL, OR WILDCAT, Middle Ground Shoal~"G''' Pool 11. SEC. T. R. M. (BOTTOM HOLE OBJECTIVE) Section 23-T8N-R13W,.~ SM 12. PERMIT NO. 13.REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED, PERFORATIONS, TESTS AND RESULTS FISHING JOBS JUNK IN HOLE AND SIDE-TRACKED HOLE AND ANY OTHER SIGNIFICANT CHANGES IN HOLE CONDITIONS. Verbal approval Hoy~le Hamilton to K. W. Lamb 3/23/78 Original Plan: Cement 13-3/8" csg with 2200 sx Class "G" neat cement Request to: Cement 13-3/8" csg with 1200 sx Class "G" w/2-1/2% prehydrated gel and tail in w/300 sx Class "G" neat. (1200 .,sx will now be equivalent to 2400 sx "neat" cement) 14. [ hereby certify t e fo ~ue a~ co~ect SIGNED TITLE Div, Opsrs, Engr, DATE NOTE-Report on this Corm is required ~or each calendar month, regardle~ o¢ the ~atus o¢ operations, and mu~ be filed in duplicate with the oil and gas conservation committee by the 15th of the succeeding month,unless otherwise directed. O/VIS/ON OF OIL ANO Conservation JAY S. HAMMOND, GOVERNOR 3001 PO££UPINE OGIVE-AN£HO£A~E ..AL.ASKA OIL ~,~D C2tS CONSERVATION CO~'~'~'T~., .,~'.L'TE.~_,~ .5~rch 6, !978 A D M ! N I S T R A T ! V E A. P P R O V A L N O. 44.31 Re: Drilling-of ?~11 C-42-23 RD in the Middle Ground Shoal Field ...Mr. R. Planqv Division .~Operations Engineer Shell Oil Company Rocky ~buntain~Operations Office 1700 Broadway Denver, Colorado Dear Sir: On March 6, 1978, Shell Oil Company applied for administrative approval to .perform the reference operation pursuant to Rule 6 of Conservation Order No. 44. This operation is designed to recover n~re reserves frc~. tb.e Middle Ground Shoal St~lct~.~re by providing an additional drainage point to achieve a better balance in the operation smd enhance the pressure maintenance progr~ and. sweep efficiencT~. The Oil and Gas Conservation C~,~gttee hereby authorizes referenced operation. (c~.) ~ 8, 1978 Middle ~ ~ C42-23 sP~/1 Oil ~ l~ezmtt ~k). 78-24 R. Plauty Division Operatioos Eng~ ~Oil~ 1700 B~ Den~r, Colorado 80290 En~ is ~ ~cved ~licati~ for permit %o drill tb~ above ref~ ~ at a location in Sectic~ 23, Township 8N, Range 1~.-~, SM. A directional ~ rivars in Alaska ~ ~ir dra/nage systems have been classified as ~~nt ~ t~ ~ or migration of an~!nm~us fish. Operati~s in ~ ~ ~ subj~ tm AS 16.50.870 and the requlatic~s prcm~dlgated thereunder (Title 5, ~ ~]ministrative Code). Prior to omnnencing. opera~~ ~ ~ ~ c°ntac+ed by tr~ ~mbitat ~ina%or's office, De~t of Fish ~ ~. Po--llution of ~ waters ~ ~ State is prohibited by AS 46, Chapter 03, Article 7 ~ tb~ regul~ atio~ ~~ated thereunder (Title 18, ALaska Adm~~ati~ ~, Chapter 70) and by the Federal Water Pollutic~ ~ ~, as ~. Pr~ to ~cix~ .operations ~vou may. be con~ by a representative of ~he Departz~nt of Fnvir~tal Cex~ervation. ~st~ant ~ ~ 38.40, ~ X-~re ~ State Leases, the Alaska F3e~t of~ is ~ notified of ~ issuance of this permit to drill. To ~ us in sdued~ field work, w~ w~a!d appreciate your noti~g this office within 48 hours a~ter ~ ~11 is .spudded. ~.% %~uld also like %O be ~fied so that a representati~ of the Division may be present to witness te ~st~ .~ of blowout .prater equi~t before surface casing shoe is ¢Irilled. R. Planty 2- M.G.S. C-42-23 ~qrch 8, 1978 in the event of suspe~mi~ or abandomment please ..Give this office adequate ~ noh~~~ SO that ~a~ may have a witness ~t. Enclosure ~t of Fish and C~m~e, Habitat Sectio~ w/o encl. Department of ~tal Conservation w/o encl. De~t of ~, ~sor, Labor Law Onmpliance Divisic~ w/o encl. SHELL OIL COMPANY 1700 B ROADWAY DENVER, COLORADO 80202 March 1, 1978 State of Alaska Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99501 Attention Mr. O. K. Gilbreth, Jr. Gentlemen: Attached in triplicate is a request to drill Middle Ground Shoal C-42-23. Included are the following: 1. Application for Administrative Approval 2. Application to Drill 3. Proposed Location Sketch and Directional Plan 4. Drilling Prognosis 5. BOP Assembly 6. $100 Filing Fee KWL: ts Yours very truly, R. Planty Division Operations Engineer Rocky Mountain Operations Office Attachments cc: w/Attachments Atlantic Richfield Company Standard Oil Company of California Amoco Production Company USGS - Alaska Form 10-401~ REV. 1-1-71 STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUBMIT IN TRit ~CATE (Other instructions on reverse side) PERMIT TO DRILL OR DEEPEN la. TYPE OF WORK DRILL ~] DEEPEN [] b. TYPE OF WELL OIL GAS SINGLE MULTIPLE [~l ,'fELL ~] ,'fELL [--] OTHER ZONE ~] ZONE I l 2. NAME OF OPERATOR Shell Oil Company 3. ADDRESS OF OPERATOR 1700 Broadway, Denver, Colorado 80290 4. LOCATION OF WELL Platform C, Leg 4, Conductor 25 :4771' S&1541'W of At surface NE Corner of Section 23, T8N, R13W, SM At proposed prod. zone 2671'N&259' W of surface 13. DISTANCE IN MILES AND DIRECTION FROM NEAREST TOWN OR POST OFFICE* 17 Miles NW of Kenai, Alaska API No. 50-133-20315 6. LEASE DESIGNATION AND SF. RIAL NO. APD 18756 7. IF INDIAN, ALLOTI'I£E OR 'FRIBE NAME 8. UNIT FARM OR LEASE NAME Middle Ground Shoal 9. WELL NO. C-42-23 10. FIELD AND POOL, OR WILDCAT Middle Ground Shoal-"G" 11. SEC., T., R., M., (BOTTOM tIOLE OBJECTIVE) Pool Section 23, T8N, R13W, SM 12. 14. BOND INFORMATION: TYPE Oil & GaS surety and/or No' TIC 136503 ,. Amount $100,000 15. DISTANCE FROM PROPOSED * [ 16.No. OF ACRES IN LEASE 17. NO,ACRES ASSIGNED LOCATION TO NEAREST I TO TtlIS WELL PROPERTY OR LEASE LINE, FT. (Alsotoneaxestdrig, unit, ifany) 3480' *(Lease Line) 5120 80 18. DISTANCE FRObl PROPOSED LOCATION 19. PROPOSED DEPTH 20. ROTARY OR (?ABLE TOOLS TO NEAREST WELL DRILLING, COMPLETED, OR APPLIED FOR, FT. 850 ft. @ "G" Pool MKR (C-32-23 9900'MD Rotary 21. ELEVATIONS (Show whether DF, RT, CR, etc.) 22. APPROX. DATE WORK WiLL START 105' DF March 20, 1978 23. PROPOSED CASING AND CEMENTING PROGRAM SIZE OF HOLE SIZE OF CASING ~IGHT PER FOOT GRADE SETTING DEPTH Quantity of cement ,,, 17~" 2 13 3/8" 54.5 & 61 K55 2500' 2200 SX (To surface) 9 7/8" 7 5/8" 29.7 & 33.7 N80 8900' 400 SX 6~" 5~" 17 N80 9900' 120 SX , , * Top of productfve zone ("G" Pool Mkr) @ 8485' TVD (8380' SS): 2100' S & 1800' W of NE corner, Section 23, T8N, R13W, SM ** See Attached Drilling Prognosis and Proposed Directional Plan. IN ABOVE SPACE DESCRIBE PROPOSED PROGRAM: If proposal is to deepen give data on present productive zone and proposed new productive zone. If proposal is to drill or deepen directionally, give pertinent data on subsurface locations and measured and true ~.~ . ,~v~srtical depths. Give blowout preventer program. ~ -~ ~,~ .; . 24. I hereby certifyj~h~ the F36reggi~ is True ~'d Correct SIGNED DATE TITLE Div Opers. Engr. (This space for State office use) SAMPLES AND CORE CHIPS REQUIRED [] ws ~] NO DIRECTIONAL SURVEY REQUIRED ~ ~ES [] ~o MUD LOG [] YES CONDITIONS OF APPROVAL, IF ANY: [~NO OTIIER REQUIREMENTS: A.P.I. NUMERICAL CODE 50-133-20315 PERMIT NO. APPOVED BY 78-24 ,, APPROVAL DATE ~ '~'~ __~_~_~ ~ TITLE C~ j y'rn~D al~Se~lnstruction On Reverse Side 8, 1978 DATE M~"ch 8. ] 978 / Conservation ./AY $. tIAMI~ON£, ~0V££~0£ .ALASKA OIL A~,~D C~S CONSERVATION C@:$.~TTTE.~E 1978 A D ~.~. I N I S T R A T I V E .A P P. R O V A L N O. 44.3]_ Drillinq of ~~ in the Middle Ground Shoal Field .~.Mr. R. Planty Division _.Operations Engineer Shell Oil Com.n. any ~ Of~-~.ce Rocky ~untain O~erations ~-" 1700 Broadway Denver, Colorado 'Dear Sir: On MarCh 6, 1978, Shell Oil company applied for administrative approval to perform the reference o~.u~ration pursuant to Rule 6 (d) of Conservation Order No. 44. This oneration is ~es~ed to recover here reserves from the ~_iddle Ground Shoal Str~ct~}re by providing an additional drainage point to achieve a better balance in the operation amd enhance the pressure mmintenance program~ and. sweep efficienqy. The Oil and Gas ConservatiOn Cors,.~ttee hereby authorizes the referenced operation. S H ELL OIL COM'PANY 1700 B ROADWAY DENVER, COLORADO 8~~ Subject: Middle Ground Shoal Cook Inlet, Alaska Platform C, Well C-42-23 NE/4, Sec. 23, T8N, R13W, SM State of Alaska Division Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99501 Attention O. K. Gilbreth Gentlemen: We would appreciate administrative approval for completion of the subject well in the "G" Pool as an exception to Rule 1 (b) and pursuant to Rule 6 (d) of Conservation Order 44. Wells C-31-23 and C-32-23 are the two permitted "G" Pool producers in the NE/4, Sec. 23-8N-13W, SM. Attached is Form 10-401 and related data for drilling of the proposed well. The proposed well is located in an area of leaseholds owned in undivided 1/3 interests by Shell, Chevron, and ARCO. As shown in the attached plat, the location is approximately 3480' from the nearest lease line to the west. Justification for this well is based upon the recovery of additional oil and gas reserves which would not otherwise be produced within the economic life of the project. The additional drainage point is designed to achieve a better balance in the operation and enhance the pressure maintenance program and sweep efficiency. Your early consideration will be appreciated to enable prompt use of an available rig. JFW:DW Yours very truly, R. Planty Division Operations Engineer Rocky Mountain Operations Office Attachments State of Alaska cc: Atlantic Richfield Co. P. O. Box 360 Anchorage, Alaska 99510 AMOCO Production Co. P. O. Box 779 Anchorage, Alaska 99510 Chevron USA, Inc. P. O. Box 7-839 Anchorage, Alaska 99510 United States Geological Survey Department of Oil and Gas 218 E. Street Anchorage, Alaska MIDDLE GROUND SHOAL C-42-25 PROPOSED LOCATION TSN-R]3W- SM C-24-14 SECTION 14 SECTION 23 -34-14 RD2 C-44-14 C-32-23 t C-31-23 C-4i-23 C-23-23, C-24-2~ C-34-23 Platform C NOTE: Represents Point of Penetration of "G" Pool ~CKR. SCALE: 1" = 1000' PROPOSED LOCATION C-42-23 2100' FNL & 1800' FEL @ "G" Pool MKR. 8485' TVD (8380' SS) k ~M-51 WELL NAME TY'PE WELL FIELD/AREA DRILLING WELL PROGNOSIS C-42-23 --D-~-v e l opment · 'Mi dd'le Ground Shoal Platform C, Leg 4, Conductor 25' 4771'S & 1541'W from NE SURFACE LOCATION (SUBJECT TO SURVEY) Corner Of- Section 23~ T~N-, R'I 3w Slq EST. G. L. ELEVATION 105' "G" Pool Zones PROJECTED TD 9900'MD OBJECTIVE DE PTHS AND HOLE CASING LOGGING MAX FORMATION SPECIAL INSTRUCTIONS SIZE PROGRAM PROGRAMS DEV. TOPS ~ ~ SAMPLES: None ® This KOP is minimum 12¼" 13-3/8" KOF~) -+840' MD consider deeper KOP open 54.5# & and drill mild "S" to 61# shape hole to avoid 17½" K-55 CORES: None conflict wi th other wells. I! ' ..,j N -+2500' MD ', ...... DST'S: None 7-5/8" 29.7# & +8000' MD ~-7/81' 33.7# - N-80 ~ ~ ii t~ ........... DEVIATION CONTROL Single shot surveys a required. SEE PROPOSED DIRECTIONAL PL SKETCH ATTACHED. ~ ~! A ~ -+8900' MD ~ HC +8960' MD CEMENT ~ ('-838D) - 13-3/8" - Cmt to surface w/2200 sacks x Class "G'l neat (50% excess) ~- 7-5/8" - Cmt w/400 sacks Class "G" *~ o 5-1/2" Liner - Sufficient cement to ~ o, fill Liner interval ~ +1 HE _+9100' MD - ,, (-8510) SUPPLEMENTAL DETAILED PROGNOSIS TO BE ~ ISSUED ON CASING/CMTG OPERATIONS ~ MUD 2 ~ HK +_9235' MD Freshwater - Lignosulfonate mud 17# -~- (-8640) C1 < 3100 ppm N-80 ~. WL < l0 cc's (2500' to 8900') SFJ ~co ~-_J~- -~ 5 cc's (8900' to TD) Liner ~-~ WT ' 9 5 10 5 ppg .(2500I to 8900'~ ~~=- HR _+9535' MD maintain minimum mud wt. in thi (-8920) ...... interval to avoid formation fra turing ia surface csg shoe:(.89'0[ to TD) - As required to control formation pressure due to water I injection. (Fracture Gradient ~ I ~ I! I~ ~ . ~D +9900' MD e_~timat~d f~n hP ll.g~ppq) ORIGINATOR: L.L. Novacek 2/1/78 ~.~ ~.A~-- DATE ENGINEERING APPROVAL: PETROLEUM: ........ DIV. DRILLING SUPT. 12"-3000 DOUBLE SH A_F,I~ER GATE 12_ - 3000 TO KILL LINE sa 5/8"- 3ooo ClW RX 57 -_ · RISER ~:,"- 3ooo ... 12"- 3000 DOUBLE STUDDED A~APTER I0 '- 5000 12"- 3000 MIDDLE DECK 24" CONDUCTOR 1:5 3/8" CAS~N~]~[~ TO CHOKE MANIFOLD DRAWN BY H.D. Kidd CHECKED BY I II J I I 111 I SHELLOILCOMPANY 3000PSi BLOWOUT PREVENTER ST~CK PLATFORM C M.G.S., COOK INLET, STATE OF ALASKA SCALE NOI'~E CHECK LIST FOR hEW WELL PERMITS 1. Is the permit fee attached .... Comp a ny ~_~) Yes Ilo Remarks 2. Is well to be located in a defined pool ........ 3. Is a registere'd survey plat attached ......... T : - q. Is well located proper distance from property line ........ 5. Is well located pFoper distance from other wells .......... 6. Is sufficient undedicated acreage available in this pool , . . .. 7. Is well to be deviated ...... · ............. /c/-~/~ 8. Is operator the only affected party ........... - //-~.~ 9. Can permit be approved before ten-day wait ............. //-~)Z~ lO. Does' operator have a bond in force 11. Is a conservation order needed . t2. ls administrative approval needed ................. ?~..._~___g 13. Is conductor string provided 14. Is enouqh cement used to circulate on conductor and surface 15. Will cement tie in surface and intermediate or production strings . 16. Will cement cover all known productive horizons ' .' . . . . ~_~ 17, Will surface casing protect fresh water zones ......... 18, Will all casing give adequate safety in collapse, tension & burst . 19. Does BOPE have sufficient pressure rating - Test to ~_~_0_~ psig 20. Has DMEM approved Plan of Operation ............ Additional Requirements' _Revised 11/17/76
