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188-099
1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: ______________________ Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 11,291 feet N/A feet true vertical 9,985 feet N/A feet Effective Depth measured 11,057 feet 9,791 feet true vertical 9,859 feet 8,821 feet Perforation depth Measured depth 10,241 - 11,088 feet True Vertical depth 9,243 - 9,876 feet Tubing (size, grade, measured and true vertical depth)2-7/8" 6.5 / L-80 9,834 MD 8,862 TVD 9,791 (MD) 319 (MD) Packers and SSSV (type, measured and true vertical depth)DB Packer 8,821 (TVD) Baker T-5 SSSV 319 (TVD) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Contact Name: Authorized Title: Contact Email: Contact Phone: 1,800 11,291 TVD measured true vertical Packer 9-5/8" 7" 8,034 MD 369 measured 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: 4. Well Class Before Work: 22 Representative Daily Average Production or Injection Data 7219 Casing Pressure STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 188-099 50-733-20403-00-00 Plugs ADL0018756 MGS C13-23 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 320-088 71 Authorized Signature with date: Authorized Name: 18 WINJ WAG 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 51 Gas-Mcf 598 N/A Oil-Bbl 6 Water-Bbl Intermediate N/A Junk 5. Permit to Drill Number: 4 Middle Ground Shoal / MGS Oil PoolN/A measured 8,034 Size 567 Production Casing Structural Liner 4,523 Length 369 1,800 Conductor Surface 5,410psi 3,810psi 24" 13-3/8" 907 777-8387 6,330psi 369 1,724 7,115 9,985 Collapse Mark McKinley mmckinley@hilcorp.com Tubing Pressure 1,130psi2,730psi Hilcorp Alaska, LLC 2. Operator Name Senior Engineer: Senior Res. Engineer: 7,240psi Daniel E. Marlowe Operations Manager Burst PL G Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Samantha Carlisle at 10:23 am, Jun 03, 2020 Daniel Marlowe I am approving this document 2020.06.03 09:45:24 -08'00' Daniel Marlowe DSR-6/3/2020gls 6/4/20 RBDMS HEW 6/3/2020 Perforate _____________________________________________________________________________________ Updated By: JLL 06/02/20 SCHEMATIC Middle Ground Shoal Well: MGS C13-23 Last Completed: 05/25/2000 PTD: 188-099 API: 50-733-20403-00 PBTD: 11,212’ TD: 11,291’ 24” RKB to MSL = 105’ MSL to mudline 73’ 7” 3 4 5 6 13-3/8” 9-5/8” 1 2 TOC @ 7,076’ Fill: WL tag @ 11,057’ WLM (06/12/2016) X XN CASING DETAIL Size Wt Grade Conn ID Top Btm 24” Conductor Surf 369’ 13-3/8” 54.5 K-55 BTC 12.615 Surf 473’ 61 K-55 BTC 12.515 473’ 986’ 54.5 K-55 BTC 12.615 986’ 1,800’ 9-5/8”43.5 N-80 BTC 8.755 Surf 3,666’ 47 N-80 BTC 8.681 3,666’ 8,034’ 7”26 L-80 LTC 6.276 6,768’ 9,555’ 35 L-80 LTC 6.004 9,555’ 11,291’ TUBING DETAIL 2-7/8” 6.5 L-80 8R EUE 2.441 Surf 9,834’ PERFORATION DETAIL Zone Top (MD) Btm (MD)Top (TVD)Btm (TVD)FT Date Status HK1A 10,241' 10,268' 9,243' 9,267' 27' 11/20/1988 HK1A 10,272' 10,278' 9,271' 9,276' 6' 11/20/1988 HK1B 10,361’ 10,365’ 9,350' 9,354' 4' 05/13/20 Open HK1C 10,379' 10,416' 9,366' 9,399' 37' 11/20/1988 HK1C 10,420' 10,437' 9,402' 9,417' 17' 11/20/1988 HK2A 10,510' 10,521' 9,479' 9,489' 11' 05/13/20 Open HK2A 10,530' 10,541' 9,496' 9,505' 11' 11/20/1988 HK2A 10,545' 10,549' 9,508' 9,512' 4' 11/20/1988 HK2B 10,578' 10,668' 9,536' 9,606' 90' 11/20/1988 HK2B 10,674' 10,716' 9,611' 9,642' 42' 11/20/1988 HK2B 10,720' 10,734' 9,645' 9,656' 14' 11/20/1988 HK2C 10,753' 10,773' 9,670' 9,684' 20' 05/13/20 Open HK2C 10,774' 10,794' 9,685' 9,700' 20' 10/21/1988 HK2C 10,809' 10,817' 9,710' 9,715' 8' 05/12/20 Open HK2C 10,819' 10,826' 9,716' 9,721' 7' 05/12/20 Open HK2C 10,828' 10,848' 9,722' 9,736' 20' 10/21/1988 HK2C 10,874' 10,894' 9,753' 9,766' 20' 10/21/1988 HK2/3 10,928' 10,933' 9,786' 9,789' 5' 05/12/20 Open HK3 10,952' 10,960' 9,800' 9,805' 8' 10/13/1988 HK3 10,968' 10,994' 9,809' 9,825' 26' 10/13/1988 HK3 11,010' 11,022' 9,834' 9,841' 12' 10/13/1988 HK3 11,026' 11,046' 9,843' 9,854' 20' 10/13/1988 HK3 11,074' 11,088' 9,869' 9,876' 14' 10/13/1988 JEWELRY DETAIL No Depth (MD) Depth (TVD)ID OD Item 34.85 Hanger – Cameron AP-FBB 11” 1 319’ 319’ 2.315 4.500 Baker T-5 SSSV 2 2,037’ 1,914’ 2.347 4.750 GLM #1 3,904’ 3,479’ 2.347 4.750 GLM #2 5,412’ 4,728’ 2.347 4.750 GLM #3 6,660’ 5,781’ 2.347 4.750 GLM #4 7,483’ 6,572’ 2.347 4.750 GLM #5 8,067’ 7,148’ 2.347 4.750 GLM #6 (GLV found at 8,093’ 9/2014 BDP) 8,578’ 7,645’ 2.347 4.750 GLM #7 8,999’ 8,054’ 2.347 4.750 GLM #8 9,357’ 8,403’ 2.347 4.750 GLM #9 9,714’ 8,747’ 2.347 4.750 GLM #10 3 9,757’ 8,788’ 2.313 3.250 Otis X Nipple 2.390 3.470 Baker 80-32 GBH locator w/3 seal subs, 4.58’ spacer sub, 2 seal subs & Muleshoe 4 9,791’ 8,821’ 7” Baker DB packer w/15’ 3.25” ID SBE & X-Over 5 9,824’ 8,852’ 2.205 Otis XN Nipple 6 9,834’ 8,862’ WLREG HK2C 10,753' 10,773' 9,670' 9,684' 20' 05/13/20 Open HK2C 10,819' 10,826' 9,716' 9,721' 7' 05/12/20 Open HK2C 10,809' 10,817' 9,710' 9,715' 8' 05/12/20 Open HK1B 10,361’ 10,365’ 9,350' 9,354' 4' 05/13/20 Open HK2/3 10,928' 10,933' 9,786' 9,789' 5' 05/12/20 Open HK2A 10,510' 10,521' 9,479' 9,489' 11' 05/13/20 Open Rig Start Date End Date Eline 5/12/20 Future 05/13/2020 - Wednesday PJSM & permit. PU EL tool suite: RS(3&2), GR/CCL & Firing Head. Surface test CCL & firing head. MU Perf Gun#4: 1.75" x 20' RTG carrier, 6 spf, 60* phase, 5.1 gm HMX Razor charge. Move to well. CCL-to-Top Shot = 10'. CCL-to Bottom Shot = 30'. T/IA/OA = 73/597. Open swab, RIH w/ Perf Gun#4 to 10850' CCL. Log up to 10675' CCL for correlation, correct +12.25'. RBIH to 10850' CCL. Log up to 10743.0' CCL to place shots on depth (10743 ' + 10' = 10753' Top Shot). Fire Perf Gun#4 to perf Zone HK2C 10753' - 10773'. Log up 200' & POOH. OOH w/ all shots fired. Surface test CCL & firing head. PU Perf Gun#5: 1.75" x 11' RTG carrier, 6 spf, 60* phase, 5.1 gm HMX Razor charge. CCL-to-Top Shot = 11.8'. CCL-to Bottom Shot = 22.8'. Move to well. Open swab & RIH to 10700' CCL, 10700' CCL, log up to 10100' CCL for correlation, correct +11.5'. Send log for correlation confirmation. Correlation log confirmed, no correction needed . RBIH to 10609' CCL. Log up to 10498.2' CCL to place shots on depth (10498.2 ' + 11.8' = 10753' Top Shot). Fire Perf Gun#5 to perf Zone HK2A 10510' - 10521'. Log up 200' & POOH. OOH w/ all shots fired. T/IA = 70/613. Surface test CCL & firing head. PU Perf Gun#6: 1.75" x 4' RTG carrier, 6 spf, 60* phase, 5.1 gm HMX Razor charge. CCL-to-Top Shot = 11'. CCL-to Bottom Shot = 15'. Move to well. Open swab & RIH to 10467' CCL, 10467' CCL, log up to 10200' CCL for correlation, correc t +9.5'. Send log for correlation confirmation. Correlation log confirmed, no correction needed. RBIH to 10462' CCL. Log up to 10350.0' CCL to place shots on depth (10350.0 ' + 11' = 10361' Top Shot). Fire Perf Gun#6 to perf Zone HK1B 10361' - 10365'. T /IA = 71/611. Wait for crane to offload boat & helicopter green deck to rig off well. Log up 200' & POOH. OOH w/ all shots fired. Rig off well and turnover to production. Job Complete. Daily Operations: Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit Number 188-099 50-733-20403-00-00 Well Name MGS C13-23 05/12/2020 - Tuesday PJSM & permit. MIRU ELU. MU EL tool suite: RS(3&2), GR/CCL & Firing Head. Surface test CCL & firing head. MU Perf Gun#1: 1.75" x 5' RTG carrier, 6 spf, 60* phase, 5.1 gm HMX Razor charge. Move to well. PT WLV & Lubricator = 250/3500 - Good Test. CCL-to-Top Shot = 10'. CCL-to Bottom Shot = 15'. T/IA/OA = 71/588/335. Open swab, RIH w/ Perf Gun#1 to 11015' CCL. Log up to 10100' CCL for correlation. Send log to Town, correct -32' & re-send corrected log. Correction confirmed. RBIH to 11015 CCL. Log up to 10918.0' CCL to place shots on depth (10918 ' + 10' = 10928' Top Shot). Fire Perf Gun#1 to perf Zone HK2/3 10928' - 10933'. Log up 200' & POOH. OOH w/ all shots fired. Surface test CCL & FH. PU Perf Gun#2: 1.75" x 7' RTG carrier, 6 spf, 60* phase, 5.1 gm HMX Razor charge. CCL-to-Top Shot = 9'. CCL-to Bottom Shot = 16'. Open swab & RIH to 10910' CCL. Log up to 10789' for correlation, correct +14'. RBIH to 10910' CCL. Log up to 10810' CCL to plac e shots on depth (10810' + 9' + 10819' Top Shot). Fire Perf Gun#2 to perf Zone HK2 10819' - 10826'. Log up 200' & POOH. OOH w/ all shots fired. Surface test CCL & FH. PU Perf Gun#3: 1.75" x 8' RTG carrier, 6 spf, 60* phase, 5.1 gm HMX Razor charge. CCL-to-Top Shot = 10.9'. CCL-to Bottom Shot = 18.9'. Open swab & RIH to 10880' CCL. Log up to 10739' for correlation, correct +15.3'. RBIH to 10881' CCL. Log up to 10798.1' CCL to place shots on depth (10798.1' + 10.9' + 10809' Top Shot). Fire Perf Gun#2 to perf Zone HK2 10809' - 10817'. Log up 200' & POOH. OOH w/ all shots fired. LD Perf Gun#3 & lubricator. Secure well and turn over to production for the night. Clean pipe & drill deck. Secure ELU. SDFN. Job in Progress. T/IA = 69/586. Fire Perf Gun#2 to perf Zone HK2 10819' - 10826' . Fire Perf Gun#6 to perf Zone HK1B 10361' - 10365'. p Shot). Fire Perf Gun#2 to perf Zone HK2 10809' - 10817'. Lo Fire Perf Gun#1 to perf Zone HK2/3 10928' - 10933' Fire Perf Gun#5 to perf Zone HK2A 10510' - 10521' Fire Perf Gun#4 to perf Zone HK2C 10753' - 10773'. L THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Daniel Marlowe Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www. oogcc.alosko.gov Re: Middle Ground Shoal Field, Middle Ground Shoal Oil Pool, MGS C13-23 Permit to Drill Number: 188-099 Sundry Number: 320-088 Dear Mr. Marlowe: Enclosed is the approved application for the 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, 19. Pnce DATED this day of March, 2020. IBDMSL4�j MAR 0 b 2020 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAr. 25 2Rn RECEIVED FEB 2 4 2020 PrS 3/ 4 -LO AOGCC 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ❑ Suspend ❑ Perforate ❑✓ 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 Q Stratigraphic ❑ Service ❑ 188-099 3. Address: 3800 Cenlerpoint Drive, Suite 1400 6. API Number: Anchorage, AK 99503 50-733-20403-00-00 - 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? CO 44A ' Will planned perforations require a spacing exception? Yes ❑ No ❑� MGS C13-23 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL0018756 Middle Ground Shoal / MGS Oil Pool ' 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): 11,291 9,985 11,057 9,859 3,426 psi N/A NIA Casing Length Size MD TVD Burst Collapse Structural Conductor 369' 24" 369' 369' Surface 1,800' 13-3/8" 1,800' 1,724' 2,730 psi 1,130 psi Intermediate Production 8,034' 9-5/8" 8,034' 7,115' 6,330 psi 3,810 psi Liner 4,523' 7" 11,291' 9,985' 7,240 psi 5,410 psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 10,241 - 11,088 9,243 - 9,876 2-7/8" 6.5 / L-80 9,834 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): Baker DB Packer & Baker T-5 SSSV 9,791 (MD) 8,821 (TVD) & 319 (MD) 319 (TVD) 12. Attachments: Proposal Summary ❑✓ Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development 2 Service ❑ 14. Estimated Dale for 15. Well Status after proposed work: Commencing Operations: 3/9/2020 OIL ❑✓ - WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Daniel E. Marlowe Contact Name: Mark McKinley Authorized Title: Operations Manager Contact Email: mmCkinle hllCor .Com ,nom Contact Phone: (907) 777-8387 Authorized Signat Date: COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 13 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: ABDMSNF' MAR 0 4 2020 Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes ❑ No d Subsequent Form Required: i C)__ i.-� O LJ / APPROVED BY 1o� Approved IbYN�A COMMISSIONER THE COMMISSION Date: 3 Q n�o 03 hir ,reda -uV �'f'� 9"R L °X� �� Submit Fonn and Fo -4 Revis 4/ 17 Appr,pplication s f f e date of approval. Attachment-s'`n Duplicate /� Z.LS . ZFi N Hacarp Alu ka, LLC Well Prognosis MGS C13-23 Well Name: MGS C13-23 API Number: 50-733-20403-00 Current Status: Gas -Lifted producer Leg: Leg #2 Estimated Start Date: 3/9/20 Rig: N/A (E -Line) Reg. Approval Req'd? 403 Date Reg. Approval Rec'vd: Regulatory Contact: Juanita Lovett (8332) Permit to Drill Number: 188-099 First Call Engineer: Mark McKinley (907) 777-8387 (0) (907) 953-2685 (M) Second Call Engineer: Dan Marlowe (907) 283-1329 (0) (907) 398-9904 (M) Current Bottom Hole Pressure: 4,405 psi @ 9,789' TVD 0.45 psi/ft (Injector gradient to Surface) Maximum Expected BHP: 4,405 psi @ 9,789' TVD 0.45 psi/ft (Injector gradient to Surface) Maximum Potential Surface Pressure: 3,426 psi Using 0.1 psi/ft gradient 20 AAC 25.280(b)(4) Brief Well Summary Well Middle Ground Shoal C13-23 is a gas -lifted oil well completed in the Hemlock sands. This well is a west flank producer with several stray hemlock sands present on logs. This work will perforate these / sands. E -line Procedure: 1. MIRU E -line, PT lubricator to 3,500 psi Hi 250 Low. 2. RU a -line guns and perforate per program. Record tubing pressures before and after perforating run. 3. RD E -line. 4. Turn well over to production. Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic HSCHEMATIC Nilcorn Alaska, LLC RKBto NGL=105 N61-tomudline73' PBTD: 11,217 TD: 11,291' Middle Ground Shoal Well: MGS C13-23 Last Completed: 05/25/2000 PTD: 188-099 API: 50-733-20403-00 CASING DETAIL Size Wt Grade F Conn ID Top Btm 24" Top (TVD) Conductor FT Surf 369' 10,241' 54.5 KI[FBTC8.681 15 Surf 473' 13-3/8" 61 1K 555 4.750 473' 986' 11/20/1988 54.5 K-5515 4.750 986' 1,800' 9 5/8" 43.5 N-805 4.750 Surf 3,666' 9,417' 47 N-801 4.750 3,666' 8,034'7„26 9,496' 9,505' L-806 4.750 fi,768' 9,555'35 8,067' 7,148' L-804 4.750 9,555' 11,291' TUBING DETAIL 2-7/8" 6.5 L-80 8R EUE 2.441 Surf 9,834' JEWELRY DETAIL Updated By: JUL 05/28/19 Depth (TVD) ID OD Item op (MD) Btm (MD) Top (TVD) Btm (TVD) FT Hanger - Cameron AP-FBB 11- 1319' 10,241' 10,268' 2.315 4.500 Baker T-5 SSSV 11/20/1988 W71483' 1,914' 2.347 4.750 GUM #1 6' 11/20/1988 3,479' 2.347 4.750 GLM #2 9,399' 37' ,728' 2.347 4.750 GLM #3 9,402' 9,417' ,781' 2.347 4.750 GLM #4 26,572' 9,496' 9,505' 2.347 1 4.750 GUM #5 10,545' 8,067' 7,148' 2.347 4.750 GLM #6 (GLV found at 8,0939/2014 BDP) HK2B 8,578' 7,645' 2.347 4.750 GUM #7 11/20/1988 8,999' 8,054' 2.347 4.750 GUM #8 42' 9,357' 8,403' 2.347 4.750 GLM #9 9,656' 9,714' 8,747' 2.347 4.750 GLM#10 3 9,757' 8,788' 2.313 3.250 OtisX Nipple 10,848' 9,722' 9,736' 2.390 3.470 Baker 80-32 GBH locator w/3 seal subs, 4.58' spacer sub, 2 seal subs & Muleshoe 4 9,791' 8,821' 9,766' 20' 7" Baker DB packer w/15' 3.25" ID SBE & X -Over 5 9,824' 8,852' 1 2.205 9,805' Otis XN Npple 6 9,834' 8,862' 10,994' 9,809' WLREG 28' 10/13/1988 HK3 11,010' 11,022' 1 9,834' Updated By: JUL 05/28/19 PERFORATION DETAIL Zone op (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status HK1A 10,241' 10,268' 9,243' 9,267' 27' 11/20/1988 HKSA 10,272' 10,278' 9,271' 9,276' 6' 11/20/1988 HK1C 10,379' 10,416' 9,366' 9,399' 37' 11/20/1988 HK1C 10,420' 10,437' 9,402' 9,417' 17' 11/20/1988 HK2A 10,530' 10,541' 9,496' 9,505' 11' 11/20/1988 HQA 10,545' 10,549' 9,508' 9,512' 4' 11/20/1988 HK2B 10,578' 10,668' 9,536' 9,606' 90' 11/20/1988 HK2B 10,674' 10,716' 9,611' 9,642' 42' 11/20/1988 HK2B 10,720' 10,734' 9,645' 9,656' 14' 11/20/1988 HK2C 10,774' 1 10,794' 9,685' 9,700' 20' 10/21/1988 HK2C 10,828' 10,848' 9,722' 9,736' 20' 10/21/1988 HK2C 10,874' 10,894' 9,753' 9,766' 20' 10/21/1988 HK3 10,952' 10,960' 9,800' 9,805' V 10/13/1988 HK3 10,968' 10,994' 9,809' 9,825' 28' 10/13/1988 HK3 11,010' 11,022' 1 9,834' 9,841' 12' 10/13/1988 HK3 11,026' 11,046' 1 9,843' 9,854' 20' 10/13/1988 HK3 11,074' 11,088' 9,869' 9,876' 14' 10/13/1988 Updated By: JUL 05/28/19 PBTD: 11,212' TD: 11,291' Size Wt Middle Ground Shoal Conn ID Top Well: MGS C13-23 24" Top (MD) Conductor PROPOSED Last Completed: 05/25/2000 Surf 369' 319' PTD: 188-099 HJlruro Alaska, LLC API. 50-733-20403-00 Surf CASING DETAIL RKBto MSL=705' MSL to mudline 73' 61 PBTD: 11,212' TD: 11,291' Size Wt Grade Conn ID Top Btm 24" Top (MD) Conductor Top (TVD) Surf 369' 319' 54.5 K-55 BTC 12.615 Surf 473' 13-3/8" 61 K-55 BTC 12.515 473' 986' 3,904' 54.5 K-55 BTL 12.615 986' 1,800' 9-5/8- 43.5 N-80 BTC 8.755 Surf 3,666' 6,660' 47 N-80 BTC 8.681 3,666' 8,034' 7„ 26 L-80 LTC 6.276 6,768' 9,555' 8,067' 35 L-80 LTC 6.004 9,555' 11,291' TUBING DETAIL 2-7/8" 16,5 L-80 8R EUE 2.441 Surf 9,834' JEWELRY DETAII No Depth (MD) Depth (TVD) ID OD Item 34.85 Top (MD) Bt II Top (TVD) Hanger -Cameron AP-FBB 11" 1 319' 319' 2.315 4.500 Baker T-555SV 9,243' 2,037' 1,914' 2.347 4.750 GLM#1 10,272' 3,904' 3,479' 2.347 4.750 GLM #2 5,412' 4,728' 2.347 4.750 GLM#3 ±4' 6,660' 5,781' 2.347 4.750 GLM#4 2 7,483' 6,572' 2.347 4.750 GUM #5 10,420' 8,067' 7,148' 2.347 4.750 GLM #6 (GLV foun=8,093'9/2014BDP) 8,578' 7,645' 2.347 4.750 GLM #7 ±11' 8,999' 8,054' 2.347 4.750 GLM #8 91496' 9,357' 8,403' 2.347 4.750 GLM #9 10,545' 9,714' 8,747' 2.347 4.750 GLM #10 3 9,757' 8,788' 2.313 3.250 OtisX Nipple 90' 11/20/1988 2.390 3.470 Baker 80-32 GBH locator w/3 seal subs, 4.58' spacer sub, 2 seal subs & Muleshoe 4 9,791' 8,821' 11/20/1988 7" Baker DB packer w/15'3.25" ID SBE & X -Over 5 9,824' 8,852' 2.205 14' Otis XN Nipple 6 9,834' 8,862' ±10,773' ±9,670' WLREG ±20' Future Proposed HK2C 10,774' 10,794' Updated By: JLL 02/14/20 PERFORATION DETAIL Zone Top (MD) Bt II Top (TVD) (ND) FT Date Status HK1A 10,241' 10,268' 9,243' 9,267' 27' 11/20/1988 HK1A 10,272' 10,278' 9,271' 9,276' 6' 11/20/1988 HK18 ±10,361' ±10,365' ±9,350' ±9,354' ±4' Future Proposed HK1C 10,379' 10,416' 9,366' 9,399' 37' 11/20/1988 HKSC 10,420' 10,437' 9,402' 9,417' 17' 11/20/1988 HK2A ±10,510' ±10,521' ±9,479 ±9489' ±11' Future Proposed HK2A 10,530' 10,541' 91496' 9,505' 11' 11/20/1988 HK2A 10,545' 10,549' 9,508' 9,512' 4' 11/20/1988 HK2B 10,578' 10,668' 9,536' 9,608 90' 11/20/1988 HK2B 10,674' 10,716' 9,611' 9,642' 42' 11/20/1988 HK2B 10,720' 10,734' 9,645' 9,658 14' 11/20/1988 HK2C ±10,753' ±10,773' ±9,670' ±9,684' ±20' Future Proposed HK2C 10,774' 10,794' 9,685' 9,700' 20' 10/21/1988 HK2C ±101809' ±10,817' ±9,710' ±9,715' ±8' Future Proposed HK2C ±10,819' ±10,826' ±9,716' ±9721' ±7' Future Proposed HK2C 10,828' 10,848' 9,722' 9,736' 20' 10/21/1988 HK2C 10,874' 10,894' 9,753' 9,766' 20' 10/21/1988 HK2/3 ±10,928' ±10,933' ±9786' ±9,789' ±5' Future Proposed HK3 10,952' 10,960' 91800' 9,805' 8' 10/13/1988 HK3 10,968' 10,994' 9,809' 9,825' 26' 10/13/1988 HK3 11,010' 11,022' 9,834' 9,841' 12' 10/13/1988 HK3 11,026' 11,046' 9,843' 9,854' 20' 10/13/1988 HK3 11,074' 11,088' 9,869' 9,876 14' 10/13/1988 Updated By: JLL 02/14/20 6 + r From: Schwartz, Guy L (CED) Sent: Monday, February 24, 2020 9:15 AM To: 'Juanita Lovett' Cc: Dan Marlowe; Joe Kaiser; Mark McKinley; samantha.carlisle@alaska.gov Subject: RE: Withdraw Sundry # 319-281 - MGS C13-23 Juanita, The AOGCC will withdraw sundry 319-281 as requested for well MGS C13-23. Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending if to you, contact Guy Schwartz at (907-793-1226 ) or (Guv.schwarfz@alaska gov). From: Juanita Lovett <jlovett@hilcorp.com> Sent: Friday, February 21, 2020 10:35 AM To: Schwartz, Guy L (CED) <guy.schwartz@alaska.gov> Cc: Dan Marlowe <dmarlowe@hilcorp.com>; Joe Kaiser <jkaiser@hilcorp.com>; Mark McKinley <mmckinley@hilcorp.com> Subject: Withdraw Sundry # 319-281- MGS C13-23 Guy, Please withdraw the above mentioned sundry. The project will not be completed at this time. Scope of work was to add perforations in the F sands. Regards, Juanita L Lovett Sr. Operations/Regulatory Tech it ' BDMS � MAR 0 91020 Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 1 Anchorage I AK 1 99503 (907) 777-8332 I ilovett@hilcoro.com The information contained in this e-mail message is confidential information intended only for the use of the recipient(s) named above. In addition, this communication may be legally privileged. If the reader of this e-mail is not an intended recipient, you have received this e-mail in error and any review, dissemination, distribution or copying is strictly prohibited. If you have received this e-mail in error, please notify the sender immediately by return e-mail and permanently delete the copy you received. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, THE STATE OIALASKA GOVERNOR MIKE DUNLEAVY Stan W. Golis Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Middle Ground Shoal Field, MGS Oil Pool, MGS C13-23 Permit to Drill Number: 188-099 Sundry Number: 319-281 Dear Mr. Golis: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 w .aogcc.olaska.gov Enclosed is the approved application for the 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, Jessie L. Chmielowski Commissioner DATED this 12 day of June, 2019. IBDMS L -/JUN 13 2019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS YDRVIT111 .YrlXrt REta` EiVD JUN 0 32018 ICx'S G�(L) It A®GCC 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ❑ Suspend ❑ Perforate Q' 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 0 Stratigraphic ❑ Service ❑ 188-099 - 3. Address: 3800 Centerpoint Drive, Suite 1400 6. API Number: Anchorage, AK 99503 50-733-20403-00-00 ' 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? CO 44A Will planned perforations require a spacing exception? Yes ❑ No ❑� MGS C13-23 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL0018756 I Middle Ground Shoal / MGS Oil Pool ' 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): 11,291 9,985 11,057 9,859 2,866 psi N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 369' 24" 369' 369' Surface 1,800' 13-3/8" 1,800' 1,724' 2,730 psi 1,130 psi Intermediate Production 8,034' 9-5/8" 8,034' 7,115' 6,330 psi 3,810 psi Liner 4,523' 7" 11,291' 9,985' 7,240 psi 5,410 psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 10,241 - 11,088 9,243 - 9,876 2-7/8" 6.5 / L-80 9,834 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): Baker DB Packer & Baker T-5 SSSV 9,791 (MD) 8,821 (TVD) & 319 (MD) 319 (TVD) 12. Attachments: Proposal Summary Q Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development Q Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 6/20/2019 OIL ❑� • WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Stan W. Golfs Contact Name: Dan Marlowe Authorized Title: Operations Manager Contact Email: dmarlowe hilo0r .Com Contact Phone: (907) 283-1329 � � Authorized Signature: Date: % 3 � 20 ( COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Uy Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes ❑ No ❑ C,/ [�BDMS"JJUN 1 3 2019 Spacing Exception Required? C o -_ L f Yes ❑ No Subsequent Form Required: l APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Form 10ds Revised 4/2017 APP Plication is veli`GRInG eAof approval L Submit oForm and Attachments In Duplicate.�41 '--4- 4"S�i% K Hilrnq Al..k., LLC Well Prognosis Well Name: MGS C13-23 API Number: 50-733-20403-00 Current Status: Gas -Lifted producer Leg: Leg #2 Estimated Start Date: June 20, 2019 Rig: N/A (E -Line) Reg. Approval Req'd? 403 Date Reg. Approval Rec'vd: Regulatory Contact: Juanita Lovett (8332) Permit to Drill Number: 188-099 First Call Engineer: Dan Marlowe (907) 283-1329 (0) (907) 398-9904 (M) Second Call Engineer: Stan Golis (907) 777-8356 (0) (281) 450-3071 (M) Current Bottom Hole Pressure: 3,790 psi @ 9,243' TVD 0.410 psi/ft (7.89 ppg) Maximum Expected BHP: 3,790 psi @ 9,243' TVD 0.410 psi/ft (7.89 ppg) Maximum Potential Surface Pressure: 2,866 psi Using 0.1 psi/ft gradient 20 AAC 25.280(b)(4) Brief Well Summary Well Middle Ground Shoal C13-23 is a gas -lifted oil well completed in the Hemlock sands. This project will add F sands not currently perforated. E -line Procedure: 1. MIRU E -line, PT lubricator to 3,000 psi Hi 250 Low. 2. RU a -line guns and perforate per program. Record tubing pressures before and after perforating run. 3. RD E -line. 4. Turn well over to production. Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic KSCHEMATIC lliln Alaska, LLC RKBto MSL=105 M i-tomudline73' PBTD: 11,212' TD: 11,291' Middle Ground Shoal Well: MGS C13-23 Last Completed: 05/25/2000 PTD: 188-099 API: 50-733-20403-00 CASING DETAIL Size Wt Grade Conn ID Top Btm 24" Top (TVD) Conductor FT Surf 369' 319' 54.5 K-55 BTC 12.615 Surf 473' 13-3/8" 61 K-55 BTC 12.515 473' 986' 3,904' 54.5 K-55 BTC 12.615 986' 1,800' 5,412' 43.5 N-80 BTC 8.755 Surf 3,666' 9-5/8" 47 N-80 BTC 8.681 3,666' 8,034' 7„ 26 L-80 LTC 6.276 6,768' 9,555' 8,067' 35 L-80 LTC 6.004 9,555' 11,291' TUBING DETAIL 2-7/8" 6.5 L-80 8R EUE 2.441 Surf 9,834' JEWELRY DETAIL No Depth (MD) Depth (TVD) ID OD Item Top (MD) 34.85 Top (TVD) Btm (TVD) FT Hanger - Cameron AP-FBB 11" 1 319' 319' 2.315 4.500 Baker T-55SSV 11/20/1988 2,037' 1,914' 2.347 4.750 GLM #1 6' 3,904' 3,479' 2.347 4.750 GLM #2 9,399' 5,412' 4,728' 2.347 4.750 GLM #3 9,402' 6,660' 5,781' 2.347 4.750 GLM #4 2 7,483' 6,572' 2.347 1 4.750 1 GLM#5 10,545' 8,067' 7,148' 2.347 4.750 GLM #6 (GLV found at 8,093'9/2014 BDP) HK2B 8,578' 7,645' 2.347 4.750 GLM #7 1 11/20/1988 8,999' 8,054' 2.347 4.750 GLM #8 42' 9,357' 8,403' 2.347 4.750 GLM#9 9,656' 9,714' 8,747' 2.347 4.750 GLM #10 3 9,757' 8,788' 2.313 3.250 OtisX Nipple 10,848' 9,722' 9,736' 2.390 3.470 Baker 80-32 GBH locator w/3 seal subs, 4.58' spacer sub, 2 seal subs & Muleshoe 4 9,791' 8,821' 9,766' 20' 7" Baker DB packer w/15' 3.25" ID SBE & X -Over 5 9,824' 8,852' 2.205 9,805' Otis XN Nipple 6 9,834' 8,862' 10,994' 9,809' WLREG 28' 10/13/1988 HK3 11,010' 11,022' 9,834' Updated By: AL 05/28/19 PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status HK1A 10,241' 10,268' 9,243' 9,267' 27' 11/20/1988 HK1A 10,272' 10,278' 9,271' 9,276' 6' 11/20/1988 HK1C 10,379' 10,416' 9,366' 9,399' 37' 11/20/1988 HK1C 10,420' 10,437' 9,402' 9,417' 17' 11/20/1988 HK2A 10,530' 10,541' 9,496' 9,505' 11' 11/20/1988 H K2A 10,545' 10,549' 9,508' 9,512' 4' 11/20/1988 HK2B 10,578' 1 10,668' 9,536' 1 9,606' 90' 1 11/20/1988 HK213 10,674' 10,716' 9,611' 9,642' 42' 11/20/1988 HK2B 10,720' 10,734' 9,645' 9,656' 14' 11/20/1988 HK2C 10,774' 10,794' 9,685' 9,700' 20' 10/21/1988 HK2C 10,828' 10,848' 9,722' 9,736' 20' 10/21/1988 HK2C 10,874' 10,894' 9,753' 9,766' 20' 10/21/1988 HK3 10,952' 10,960' 9,800' 9,805' 8' 10/13/1988 HK3 10,968' 10,994' 9,809' 9,825' 28' 10/13/1988 HK3 11,010' 11,022' 9,834' 9,841' 12' 10/13/1988 H1(3 11,026' 11,046' 9,843' 9,854' 20' 10/13/1988 HK3 11,074' 11,088' 9,869' 9,876' 14' 10/13/1988 Updated By: AL 05/28/19 PROPOSED Ililmrp Alaska, LLC RKBto MSL=105' NLSLtomudline73' PBTD: 11,212' TD: 11,291' Middle Ground Shoal Well: MGS C13-23 Last Completed: 05/25/2000 PTD: 188-099 API: 50-733-20403-00 CASING DETAIL Size Wt Grade Conn ID Top Btm 24" Top (TVD) Conductor FT Surf 369' 319' 54.5 K-55 BTC 12.615 Surf 473' 13-3/8" 61 K-55 BTC 12.515 473' 986' 3,904' 54.5 K-55 BTC 12.615 986' 1,800' 9-5/8" 43.5 N-80 BTC 8.755 Surf 3,666' 6,660' 47 N-80 BTC 8.681 3,666' 8,034' 7„ 26 L-80 LTC 6.276 6,768' 9,555' 8,067' 35 L-80 LTC 6.004 9,555' 11,291' TUBING DETAIL 2-7/8" 6.5 L-80 8R EUE 2.441 Surf 9,834' JEWELRY DETAIL No Depth (MD) Depth (TVD) ID OD Item Top (MD) 34.85 Top (TVD) Btm (TVD) FT Hanger -Cameron AP-FBB 11" 1 319' 319' 2.315 4.500 Baker T-5 SSSV Future Proposed 2,037' 1,914' 2.347 4.750 GLM#1 27' 3,904' 3,479' 2.347 4.750 GLM #2 9,276' 5,412' 4,728' 2.347 4.750 GUM #3 9,366' 6,660' 5,781' 2.347 4.750 GLM #4 2 7,483' 6,572' 2.347 4.750 GLM#5 10,530' 8,067' 7,148' 2.347 4.750 GLM #6 (GLV found at 8,093'9/2014 BDP) HK2A 8,578' 7,645' 2.347 1 4.750 GLM #7 11/20/1988 8,999' 8,054' 2.347 4.750 GLM#8 90' 9,357' 8,403' 2.347 4.750 GLM#9 9,642' 9,714' 8,747' 2.347 4.750 GLM #10 3 9,757' 8,788' 2.313 3.250 OtisX Nipple 10,794' 9,685' 9,700' 2.390 3.470 Baker 80-32 GBH locator w/3 seal subs, 4.58' spacer sub, 2 seal subs & Muleshoe 4 9,791' 8,821' 9,736' 20' 7" Baker DB packer w/15' 3.25" ID SBE & X -Over 5 9,824' 8,852' 2.205 9,766' Otis XN Nipple 6 9,834' 8,862' 10,960' 9,800' WLREG 8' 10/13/1988 HK3 10,968' 10,994' 9,809' Updated By: 1LL 05/28/19 PERFORATION DETAIL one Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Fl ±9872' ±9,884 ±8,898' ±$910' ±12' Future Proposed HK1A 10,241' 10,268' 9,243' 9,267' 27' 11/20/1988 HK1A 10,272' 10,278' 9,271' 9,276' 6' 11/20/1988 HKSC 10,379' 10,416' 9,366' 9,399' 37' 11/20/1988 HK1C 10,420' 10,437' 9,402' 9,417' 17' 11/20/1988 HK2A 10,530' 10,541' 9,496' 9,505' 11' 11/20/1988 HK2A 10,545' 1 10,549' 9,508' 9,512' 4' 11/20/1988 HK2B 10,578' 10,668' 9,536' 9,606' 90' 11/20/1988 HK2B 10,674' 10,716' 9,611' 9,642' 42' 11/20/1988 HK2B 10,720' 10,734' 9,645' 9,656' 1 14' 1 11/20/1988 HK2C 10,774' 10,794' 9,685' 9,700' 20' 10/21/1988 HK2C 10,828' 10,848' 9,722' 9,736' 20' 10/21/1988 HK2C 10,874' 10,894' 9,753' 9,766' 20' 10/21/1988 HK3 10,952' 10,960' 9,800' 9,805' 8' 10/13/1988 HK3 10,968' 10,994' 9,809' 9,825' EL 10/13/1988 HK3 11,010' 11,022' 9,834' 91.841' 12' 10/13/1988 HK3 11,026' 11,046' 9,843' 9,854' 20 > 10/13/1988 Hi 11,074' 11,088' 9,869' 9,876' 14' 10/13/1988 Updated By: 1LL 05/28/19 Safety Valve & WeII Pressures Test Report Reviewed ~ ` ; P.1. Supr f = z ~ ~ ~ Comm Pad: MGS_XTO_C_PLATF InspDt: 2/22/2008 °~Inspected by John Crisp Interval InsplYo svsJCr080225134306 Related Insp: Field lvame MIDDLE GROUND SHOAL Operator XTO ENERGY INC Operator Rep Barney Phillips Reason 90-Day `~ Sre: Inspector --- -- -- - -- _ Well Data Pilots SSV SSSV Shutln Dt Well Type Well Pressures Gas Lit Waiver Comments ' Well Permit Separ Set UP Test Test Test Date SI OrI,WAG,GINJ, Inner Outer Tubing Number Number PSI PSI Trip Code Code Code GAS.CYCLE. Sl PSt PCr ver va~iN., ve~ini.. ~ C12 23 1900200 -- - -- -- C13 23 1880990 13A 23 ~ _ 1901060 _ C21 23 ~ !890870 68 - 68 8 ---- 68 ~ 37 ----t 37 _ 0 1 37 - 37 _ P P P P P - P P P P -- - 1-OIL -- - 1-OIL -OIL --- 1-OIL - --- - - - ---- - - --- - - - - - -- -_"- __l ' -"--- +- - _ t ~ - - - --- -- - --_"-' --- --- - -- - -- - - -- - --- _- - - ---------- --------1 I SSSV t f W/L 2l 26 i 1890040 ~ C2I 2 ~ - - - 0 ` - - -- - r- P - P - -- ~ - - -- - - - -- ou or _worlc - ~ -- - - - - - 1 ~ A 3 1910440 ~ __ ~-- C22-26RD ~ 1760650 --- C22A-26LN ~ 2041820 ~ C31-26RD 2041400 68 68 - 68 ~ 68 = - i 0 0 ~ - -- 0~ ~ 0 T r- - _ ---- ~ I - -..- P P --- P --- P i = p P P - P - -- ..-- - - - 1 OIL 1-OIL - l-OIL ----- 1-OIL - ~ - ~ .... -- - - _, ---" -~ _. - ------r ~ _ _ . - - - - --- ~ _ T ~ _ _ - - - - --- - - -- _ _ _-- --= _ _ - - - --- -1 C32-23LW 2020340 - --- --- --- - C42-23 1780240 68 ~ -- 68 0 I r- 0 - - - P -- P P P ----- 1-OIL ---- - 1-OIL - - ~ - -- - - - -- --- _- - - --""-"~ _1 +-- -- ' _ - - - --- ------ ---~ C43-14 - - _-- 1881320 _68 ~ 0 ~ _- _ ~ _ P_ _ L P i __ -- --1-OIL ~ ----- -- • Comments Performance Pilot numbers listed on wells C12-23 & C13-23 are for the pilots on the separators. Individual wells are --- ------ l / not equiped with pilots on this platform. ;/ ~ Wells Components Failures Failure Rate 12 25 0 ~,~~ MAR ~ ~ 200£ • Tuesday, February 26, 2UU8 I MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Robert Christenson Chairman DATE: 05/23/2000 THRU: Blair Wondzell P.I. Supervisor FROM: John Cris Petroleum I~;fspector NON- CONFIDENTIAL SUBJECT: Blowout Preventer Test Cross Timbers C Cross Timbers C Platform C13-23 PTD 88-99 Sundry #300-093 Middle Ground Shoals Operator Rep.: Larry Driscall Contractor Rep.: Jerry Sandich Op. phone: 776-5251 Rig phone: 776-5251 Op. E-Mail: Rig E-Mail: Test Pressures Rams: 5000 Annular: 2500 MISC. INSPECTIONS: P/F P/F Location Gen.: P Sign: P Housekeeping: P Rig cond: P PTD On Location yes Hazard:.yes Standing Order: ~yes BOP STACK: Quantity Size P/F Annular Preventer 1 13 5/8" P Pipe Rams I 2 7/8" P Lower Pipe Rams Blind Rams 1 13 5/8" P Choke Ln. Valves 1 3" P HCR Valves I 3" P Kill Line Valves 2 2" P Check Valve none Choke: 5000 TEST DATA FLOOR VALVES: Quantity P/F Upper Kelly not tested Lower Kelly not tested Ball Type 1 P Inside BOP 1 P CHOKE MANIFOLD: Quantity P/F No. Valves 12 P Man. Chokes 1 P Hyd. Chokes 1 P MUD SYSTEM: Visual Alarm Trip Tank ok Pit Level Indicators ok Flow Indicator ok Meth Gas Detector not tested H2S Gas Detector not tested ACCUMULATOR SYSTEM: Time/Psi P/F System Pressure 2950 After Closure 1950 200 psi Attained 26 sec. Full Pressure 2 min. 17 sec. Blind Covers (All Stations): yes N2 Bottles (avg): 6 @ 2500 psi. Test's Details I traveled to Cross Timbers C Platform to witness the initial BOP test on well C13-23 in Middle Ground Shoals Field. This is a tubing change working under Sundry Approval #300-093. The Kelly will not be used on this well so the Kelly valves were not tested. The Platform Electrician was not on board ~ time of test, gas detector testing would be performed when he arrived. No failures were witnessed. Good Test. Total Test Time: 4 hours Number of Failures: CC: none Attatchments: none BOP X Timbers PLT. 5-23-00jc.xls 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~ Change approved program ~ Pull tubing ^ Variance ~ Pertorate ~ Other 2. Name of Operator Cross Timbers Operating Compan.y 3. Address 210 PARK AVE., SUITE 2350 OKLA. CITY, OK. 73102 5. Type of Well: Development X Exploratory Stratigraphic Service 4. Location of well at surface "C",Leg 4,Cond. 29, 499'FSL & 1534' FEL of Sec. 23,TSN,R13N, A.S.P. 6. Datum elevation (DF or KB) 105' DB 7. Unit or Property name Middle Ground Shoal 8. Well number C13-23 At top of productive interval @1407' FSL & 4065' FEL of At effective depth Sec. 23,T8N,R13W, SM. At total depth @1,480' FSL & 3226' FEL of Sec. 23,TSN,R13N 9. Permitnumber 88-99 10. APInumber 5o- 733-20403-00 11. Field/Pool "G" Pool feet 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 11,291' 9985' 11,212' 9,943' feet feet feet feet Plugs (measured) Junk (measured) Casing Length Structural Conductor Surface 1,800' Intermediate8,034' Production Liner 4,493' Perforation depth: Size Cemented Measured depth True vertical depth 13-3/8",61#,K-55 BT 1012 sx "G" 9-5/8",43.5-47#,N80 560 sx "G" 1,800' 8,034' 7" ,26-35#, L-80 measured 9,206' - 10278' true vertical 8,458' - 9,341' 1416 sx 11,921' ORIGINAL Tubing (size, grade, and measured depth) 2- 7/8",6.5#,L-80 EUE 8RD @ O' - 9,834'. Packers and SSSV (type and measured depth) BAKER DB PACKER @ 9791'. 1734' 7,115' 9,985' RECEIVED APR 10 2000 Ala a Oil & Cons. Commis¢on 13. Attachments Description summary of proposal Detailed operations program X BOP sketch 14. Estimated date for commencing operation 15. Status of well classification as: 04/24/2000 16. If proposal was verbally approved Oil X Gas ~ Name of approver Date approved Service 17. I h~ :e_.rt,~/~.~j,~re. goi~ng is~true and correct to the best of my knowledge. Signed~tr~_~~'''~' ~ ?~'¢rY,,,'o°'¢'~ Title Sr. Engi neeri ng Tech Suspended Date 04~06/2000 FOR COMMISSION USE ONLY Conditions of approval: Notify Commission. s,9, representative may witness BOP Test v Loca Plug integrity tion clearance Mechanical Integrity Test ~ Subsequent form required 10- JApprova, No. ,b6~- Approved by order of the Commission ORIGINAL SIGNED, BY Robert N. Chdstenson Commissioner Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE CROSS TIMBERS OPERATING COMPANY MGS C13-23 COOK INLET, ALASKA WELL DATA SURFACE CASING: PRODUCTION CASING: LINER: TUBING: PERFORATIONS: OBJECTIVE: 13 3/8" 54.5, 61# K55. Set ~ 1802'. Cmt w/962 sx. 9 5/8" 43.5, 47# N80. Set at 8034'. Cmt w/560 sx. 7" 26, 35 # L80. TOL ~ 6779'. Set ~ 11212'. Cmt w/1415 sx. 2 7/8" 6.5# N80 ABMOD EUE ~ 9834'. HC-HD 10241-10268', 102720-10278' HE-HF 10379-10416', 10420-10437' HI-HK 10530-10541 ', 10545-10549' HK-HN 10578-10668', 10674-10716', 10720-10734' I-IN-HR 10774'-10794', 10828'-10848', 10874'-10894' HR-HZ 10952'- 10960', 10968'- 10994', 11010'- 11022', 11026'- 11046', 11074'-11088' Repair hole in tubing: Fish lost WL tools and replace tubing, GLMs and SSSV. Note: H2S 0 ppm on 3/30/2000. This well will "no flow." If well control is needed, FIW will control this well. Have mud and weight material on location during workover operations. 1. RU SL. Test lubricator. Pull ball valve and GLV #7. Run and set a plug in XN nipple @ 9825'. RD SL. . Skid rig and RU. Load well w/FIW. Install BPV. ND tree and NU BOP's. Test BOP's. PU out ofpkr and circ well w/FIW. POOH w/2 7/8" 6.5# NS0 8R EUE tbg. LD and send to shore for inspection. Check all tbg for NORM per OIL 1.00(n)-I (Revised 1/10/92). "' Cap b/f Top Btm Bbis .... Annular Cap wi 2 718" tbg 9 5/8"43.5# x 2 7/8" annuJus 0.0664 0 3666 243 9 5/8"47# x 2 7/8" annulus ~ 0.0652 3666 6779 203 7" 26# x 2 7~8" annulus 0.0302 6779 9555 84 7" 35# x 2 7~8" annulus 0.0270 9555 9791 6 537 Total Annular Fluid to top of Pkr Cap hole w/o tbg 9 5/8" 43.5# 0.0744i 0 3666~ 273 9 5/8"47# 0.0732 '3666 6779 228 !7" 26# 0.0382 6'779 9555 106 '7" 35# 0.035 9555 9791 8 61'5 , Cap of 2 7~8" tbg 0.00579 0 9791 57 RECEIVED APR 1 0 2000 Alaska Oil & Gas Coes. Commi m Anchorage TIH w/Bkr G locator seal assy (2 seal units, 5' spacer tube, 1 seal unit and G locator), ljt of 2 7/8" 6.5# N80 8R EUE tbg, Otis X nipple 2.313" ID, 2 7/8" 6.5# NS0 8R EUE tbg and GLM as follows: (Existing GL design. Prior to running pipe, check with the Operations Engineer for modified design.) Item 'DVD MD Bkr T5 SSSV 317 317 GLM #1 1700 1771 GLM #2 3243 3629 GLM #3 4576 5221 GLM ~ 5688 6557 GLM #5 6584 7495 GLM ~5 7327 8250 GLM #7 7932 8874 GLM #8 8397 9351 GLM #9 8706 9672 Locate Bkr DB pkr ~ 9791' MD. Land tbg in neutral. ND BOP NU tree and return well to production. 4. RU SL. Test lubricator. RIH and retrieve plug in XN nipple ~ 9825'. POOH. RD SL. Return well to production. Charles Po~ ~ - ' Doug I~Ia4shal[ Doug S6hUltze d Date ~Da~:~ Date Date RECEIVED APR MGS C13-23 Cook Inlet, Alaska Leg 2, Conductor 16 APl No.: Spud: , ,rnDers uperating Company Present Completion Checked by: KB: ' Water Depth: Tubing: 2 7/8", 6.5~, N80, AB-MOD EUE @9834' Surf Csg: 13 3/8", 54.5-61 lb, K55 BTC. Set @ 1802'. Crnt°d w/962 sx. Prod Csg: 9 5/8", 43.5-47 lb, N80, BTC. Set @ 8304'. Cmt'd w/560 sx. Item TVD MD Ptro Port Flopetrol Safety VIv 317' 317' Gas Lift Mandrel #1 1700' 1771' 899 1/8 Gas Lift Mandrel #2 3243' 3629' 938 3/16 Gas Lift Mandrel #3 4576' 5221' 935 3/16 Gas Lift Mandrel ~4 5688' 6557' 930 3/16 Gas Lift Mandrel #5 6584' 7495' 923 3/16 Gas Lift Mandrel #6 7327' 8250' 972 1/4 Gas Lift Mandrel #7 7932' 8874' orifice 1/4 Gas Lift Mandrel #8 8397' 9351' 938 1/4 Gas Lift Mandrel ~:J 8706' 9672' Or. 5/16 Kickover tool stuck in GLM ~ Liner Csg: 7", 26 lb, L80 LTC. Set ~ 6779'-9555'. 7", 35 lb., LB0, LTC. Set @ 9555'-11212'. Cmt wi 1415 sx. PBTD: TD; 11212'(Landing Collar), Tops of FlagJoints @10331' &lO559'(D.P.) 11291' One Jr. Tubing 2-7/8" otis "xo" Sliding Sleeve @ 9746' MD (8777' TVD) One Jt. Tubing Baker "G" Locator w/2 seal units, 5' Spacer Tube, Add Seal Units & Muleshoe to Utilize Available Seal Bore @ 9791' MD (8820' TVD) Baker "DB" Pact~er ID = 3.25" wi 15' SBE & X-Over @ 9791' MD (8820' TVD) (9762' DIL) 15' 2-7/8" EUE PUP, Top @ 9810' MD (8840' TVD) 2-7/8" Otis "XN" Nipple ~ 9825' MD (8854' 'I'VD) 8' 2-7/8" EUE PUP Otis Re-entry Guide/Shear Out Sub no lower than 9834' MD (8862' TVD) (9805 DIL) GR-GS: HC-HD: Atlas HE-HF: HI-HK: HK-HN: HN-HR: HR-HZ: holes) To be perforated later( Top of GR ~ 9837' DI 10241'-10268' & 10272'-10278' (4SPF 2-1/8" Silver)et) 10379'-10416' & 10420'-10437' (Same) 10530'-10541' & 10545'-10549' (Same) 10578'-10668' & 10674'-10716' & 10720'-1072 (Same) 10774'-10794' & 10828'-10848' & 10874'-108£ (1/2 SPF 30 holes) 10952'-10960' ' 10968'-10994' & 11010'-1102; 11026'-11046' & 11074'-11088' (1/2 SPF 40 RECEIVED APR 10 2000 Alaska 0il & Gas Cons. Commiss~ Anchorage Shell Western E&P Inc. An affiliate of Shell Oil Company P. O. Box 576 Houston, TX 77001 October 3, 1995 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Gentlemen: SUBJECT: SUBMITTAL OF REPORT OF SUNDRY WELL OPERATIONS (FORM 10-404) for MIDDLE GROUND SHOAL C13-23 Enclosed in duplicate is the Report of Sundry Well Operations for Middle Ground Shoal C13-23. Operations were aborted for the soak/wash/squeeze coiled tubing stimulation since we were unable to fish a broken kick-over tool from the second gas lift mandrel. We are no longer planning to perform the work approved by the Commission on April 24, 1995. If you have any questions or wish to discuss, please call Marcus Winder at (713) 544-3797 or Alan Foglesong at (907) 283-2509. Sincerely~ ~. S. Nady Manager - Asset Administration Western Asset Enclosures MGS404.DOC- 1 OCT i i 1995 Alaska Oil & Gas Cons. Commission Anchorage 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 X 2. Name of Operator Shell Western E&P Tnc. 3. Address P.O. Box 576, Houston, TX 77001-0576 4. Location of well at surface PLATF C, LEG 4, COND 29, 499' FSL & At top of productive interval 1407' FSL & 4065' FEL SEC. 23, T8N, At effective depth At total depth 1480' FSL & 3236' FEL SEC. 23, T8N, 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured 5. Type of Well: Development X Exploratory Stratigraphic . Service 1534' R13W, FEL SEC. 2.3j SM R13W, SM 6. Datum elevation (DF or KB) ]05' ER feet 7. Unit or Property name NIDDLE GROUND SHOAL 8. Well number C13-23 ~ ~j~t number/approval number e_r ~ 95-078 O. APl number $o-133-20403 11. Field/Pool MGS "G" POOL 11291 feet 9985 feet 11212 feet 9943 feet Plugs (measured) Junk(measured) 3613' & 7113' Length Size Cemented Measured depth 1802' 13-3/8" 962 SX 1800' (BROKEN KICKOVER f~r / True vertical depth / / 1734' 8034' 9-5/8" 560 SX 8034' 7115' 4512' 7" 1415 SX 11291' 9985' 10241' - 11088' true vertical ~ ~. 9243' - 9890' Tubing (size, grade, and measured depth) /-Uaska 2-7/8", 6.5#. N-80 EUE e 9834' Packers and SSSV (type and measured depth) Ar~ol~orsg8 BAKER "DB" PKR e 9791'; FLOPETROL SAFETY VALVE e 317' 13. Stimulation or cement squeeze summary Intervals treated (measured) NA Treatment description including volumes used and final pressure 14. Prior to well operation 261 Subsequent to operation 269 Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure 66 I 735 85 68 I 775 70 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. S'gned/,/~r_,aX~,~~f~R, $. NADY Form 10-404 Rev 06/15/88//. Title MGR. - ASSET ADMIN. Date 10-03-95 - 44- SUBMIT IN DUPLICATE · ~om' EP388TA/~--~35 '7~' EP381A_AF--~35 A A FOGLESONG Date and =~me EP38DLM --VM35 04/24/95 09:31-59 D L NLARS~L F~ m: TOM REESE S, ject: C13-23 ON 4-21-95. FISH BROKEN KICKOVER TOOL. RIH WITH 2.44 SCR3~TCHER. STOPPED AT 9317 (WLM). POOH. RIH WITH 2.25 IMPRESSION BLOCK. STOPPED AT #2 GAS-LIFT PLANDRELL AT 3605 (WLM). POOH. H_AD IMPRESSION OF GAS-LIFT VALVE. RIH WITH 2.0 IMPRESSION BLOCK. STOPPED AT 3613 (WLM). POOH. HAD IMPRESSION OF WIRE. NO NLARKS INDICATING GAS-LIFT VALVE. LAST PRODUCTION TEST WAS AS FOLLOWS: GROSS 262; CUT .5; CLEAN 261; INJ 614; GOR 66; GOR 253; TBG 85; CSG 730; SCP 66. END OF NOTE Alaska Oil & Gas Cons, Cor~misslori Anchorage - 1 - :om: EPS 88TAR--VM35 Eo' F. P381AAF--VM35 A A FOGLESONG Date and LAme EP38DLM --VM35 04/24/95 09:39:57 D L MARSHALL F~ m: TOM REESE S~ ject: C13-23 ON 4-22-95. FISH BROKEN KICKOVER TOOL. RIH WITH 2.28 TAPERED GAUGE RING. STOPPED AT 3613 (WLM). 8' BELOW GAS-LIFT VALVE. POOH. HAD MARKS ON TAPERED GAUGE RING INDICATING WIRE. RIH WITH 2.5 WIRE GRAB. STOPPED AT 3605 (WLM). GOT BY GAS-LIFT MANDRELL. STOPPED AT 3613 (WLM). COULD NOT LATCH ANY WIRE. FINALLY GOT BY WIRE. TRIED FOR 1 HOUR TO FISH WIRE CAND COULD NOT GET A_HOLD OF A/~Y. RIH WITH 2.0 IMPRESSION BLOCK ON 2.25 CENTALIZER. GOT BY WIRE AT 3613 (WLM). RIH AND STOPPED AT 7113 (WLM).POOH. HAD IMPRESSION OF WIRE. RIH WITH 2.5 WIRE GRAB. GOT BY WIRE AT 3613 (WLM). STOPPED AT 7113 (WLM). COULD NOT GET A_HOLD OF ANY WIRE AT 7113 (WLM). FINALLY GOT BY WIRE AT 7113 (WLM). HAD TROUBLE GETTTING BACK THROUGH WORE. . DECIDED IT WAS TIME TO REGROUP. RIH AND SET OTIS 2.313 DKX BALL VALVE AT 285 (WI24). FUNCTION TESTED BALL VALVE. TEST OK. END OF NOTE Oil & Bas ons. ommission Anonora . - 1 - April 2O, 1995 Shell Western E&P Inc. An affiliate of Shell Oil Company 130 Trading Bay, Suite 310 Kenai, AK 99611 (907) 283-3096 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: SUBMISSION OF FORM 10-403 APPLICATION FOR SUNDRY APPROVAL TO CLEAN OUT AND ACID TREAT M.G.S. WELL NO. C13-23. ~.--~ ? Enclosed in triplicate is the Application for Sundry Approval, Form 10-403, to stimulate MGS C13-23 with a soak/wash/squeeze method utilizing 7-1/2% HCI. Operations are expected to begin May 10, 1995. If you have any questions, please don't hesitate to call me at (907) 283-2509. Thank you! Sincerely, Alan Foglesong Senior Production Engineer Enclosures STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon Suspend After casing Repair well Change approved program .... Operation shutdown ,, Re-enter suspended well Plugging Time extension Stimulate ~( Pull tubing Variance Perforate Other 2. Name of Operator Shell Western E&P Inc. 3. Address 130 Trading Bay, ~310 Kenai, AK 99611 5. Type of Well: Development Exploratory Stratigraphic ~,, Service 4. location of well at surface Plat, C, Leg 4, Cond. 29, 499'FSL&1534'FEL of Sec. 23, T8N, R13W, 5H 6. Datum elevation (DF or KB) 105'KB 7. Unit or Property name Hiddle Ground Shoal 8. Well number C13-23 feet At top of productive interval $1407'FSL & 4065'FEL of Sec. 23, T8N, R13W, SH At effective depth At total depth Ia 1480'FSL & 3236'FEL of Sec. 23, T8N, R13W, SM 9. Permit number 88-99/91-089 10. APl number ~o- 833-20403 11. Field/Pool HGS "G" Pool 12. Present well condition summary Total depth: measured 11291 feet true vertical 9985 feet Effective depth: measured 11212 feet true vertical 9943 feet Plugs (measured) Junk (measured) ORIGINAL Casing Length Structural Conductor 1802 Surface Intermediate 8034 Production 4512 Liner Perforation depth: measured Size Cemented 13-3/8",61#,K-55BTC 962 sx 9-5/8",43.5-47#,N80 560 sx 7", 26-35~, L-80 1415 sx 10241' - 11088' true vertical Measured depth 1800 8034 11291 9243' 9890' Tubing (size, grade, and measured depth) 2-7/8",6.5~,N-80 EUE e 9834' Pacers and SSSV (type and measured depth) Baker "DB" Packer ~ 9791'; Flopetrol safety valve $ 317' True vertical depth 1734 7115 9985 RECEIV£D APR 24 1995 AlaSka 0il & Gas Cons. Commission Anch0rm P 13. Attachments Description summary of proposal X Detailed operations program BOP sketch 14. Estimated date for commencing operation May 10, 1995 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil X Gas Service Suspended 17. I hereby ce~rtify that the for_~.going is. true and correct to the best of my knowledge. Signed ~'~,-¢,~._, (~?~1~7~ Title Sr. Production 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 required 10- ~/O~ Approved by order of the Commission Original Signed By David W. Johnston JApproval No. Approved Copy RCturne/:l .... comr~is~ioner Date Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE APPLICATION FOR SUNDRY APPROVALS FORM 10-403 ATTACHMENT DESCRIPTION SUMMARY O~FPROPOSAL MIDDLE GROUND SHOAL WELL NO. C13-23 We recommend a clean out and xylene/acid treatment tubing unit (CTU) utilizing the Soak/wash/squee of MGS C13-23 via coiled The latest test was March 17, 1995 at 265 BPD Gross o · ze method of stimulation. clean. A 50 BOPD .prOduction increase is expected from SUccessful stimulation of this Well via coiled tubing unit. , .3~ cut, and 264 BOPD 1. Fill Wellbore via the annulus with Filtered Inlet Water (FIW). 2. Rig up Coiled Tubing Unit (CTU), xylene/acid treatment materials & equipment, and return fluid processing materials & equipment 3. RIH with Coiled tubing to PBTD. Xylene/Acid treat via CTU with 7-1/2% hydrochloric (HC1) acid. Dispose of contaminated fluids in C44-141 that Will be sent to Production facilitiesNeutralize all return fluids · · 6. Return well to production via gas lift. ~ REC£1VI D APR 24 1995 oil & oas cons. commission Anchora~ ~' 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 · APR 2 4 1995 AJaska Oil & Gas Cons, Commission Anchora~ ~ COMPLETION EQUIPMENT DETAIL SHEET MGS C13-23 12/12/88 TBG SLM NO. ITEM TVD. MD. PSI OR 1. FLOPETROL SAFETY VALVE 317 2. GAS LIFT MANDREL #1 1700 3. GAS LIFT MANDREL #2 3243 4. GAS LIFT MANDREL #3 4576 5. GAS LIFT MANDREL #4 5688 6. GAS LIFT MANDREL #5 6584 7. GAS LIFT MANDREL #6 7327 8. GAS LIFT MANDREL #7 7932 9. GAS LIFT'MANDREL #8 8397 10. GAS LIFT MANDREL #9 8706 iOA. ONE JT TUBING 11. 2'7/8" OTIS "XO" SLIDING SLEEVE 8777 9746 12. ONE JT TUBING 13. BAKER "G" LOCATOR W/ 2 SEAL UNITS, 5' SPACER TUBE, ADD SEAL UNITS & MULESHOE TO UTILIZE AVAILABLE SEAL BORE 8820 9791 14. BAKER "DB" PACKER ID = 3.25" W/ 15' SBE & X-OVER 8820 15. 15' 2-7/8" EUE PUP, TOP @ 8840 16. 2-7/8" OTIS "XN" NIPPLE 8854 17. 8' 2-7/8" EUE PUP '18. OTIS RE-ENTRY GUIDE/SHEAR OUT SUB NO LOWER THAN: 8862 317 1771 899 1/8 3629 938 3/16 5221 935 3/16 6557 93O 3/16 7495 923 3/16 8250 972 1/4 8874 952 1/4 9351 938 1/4 9672 OR 5/16 9791 (9762 DIL) 9810 9825 9834 (9805 DIL) CASING 13 3/8", 54.5-61#,K-55, BTC @ 1802' w/962 sx 9 5/8", 43.5-47#, N-80, BTC @ 8034' w/560 sx 7" 26#, L-80, LTC @ 6779 - 9555' 35#, L-80, LTC @'9555 - 11212' PBTD = 11,212' (LANDING COLLAR), TOPS OF FLAGJOINTS @ 10,331 & 10,559' (D.P.) TD = 11,291' TUBING 2 7/8", 6.5#, N-80, AB-MOD EUE @ 9834' PERFORATED ZONE GR-GS HC-HD HE-HF HI-HK HK-HN HN-HR HR-HZ INTERVAL (DIL DEPTHS) TO BE PERFORATED LATER (TOP OF GR IS @ 9837' (DIL) 10,241-10,268' & 10,272-10,278' 4SPF 2-1/8" ATLAS SILVERJET 10,379-10,416' & 10,420-10,437' 4SPF 2-1/8" ATLAS SILVERJET 10,530-10,541' & 10,545-10,549' 4SPF 2-1/8" ATLAS SILVERJET 10,578-10,668' & 10,674-716 & 10,720-10,734' 4SPF 2-1/8" ATLAS SILVERJET 10,774-94', 10,828-48', 10,874- 94', 1/2SPF 30 HOLES 10,952-60', 10,968-94', 11010- 22', 11,026-46', 11,074-88' 1/2SPF 40 HOLES Shell Western E&P Inc, Q 601 West Fifth Avenue · Suite 800 Anchorage, Alaska 99501 December 4, 1991 State of Alaska Alaska Oil and Gas Conservation Commission ATTN: Larry Grant 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Grant: SUBJECT: TRANSMITTAL OF THE DIRECTIONAL SURVEY FOR MIDDLE GROUND SHOAL WELL NUMBER C13-23 Per your verbal request on December 3, 1991, enclosed is one copy of the Directional Survey report performed while drilling Middle Ground Shoal well number C13-23. If you need additional information, please don't hesitate to call me at (907) 263-9613. Very Truly Yours, Susan B. Brow~-Maunder sr. Environmental Technician Alaska Operations SBBM/JLT Enclosures SBBM\120491b.doc Dc' w/o enclosures R. G. Blackburn- Anchorage B. S. Jacobs - WCK 44!0 Regulatory Affairs File - 5.6120 C13-23 Correspondence File - 5.91 Production File - WCK 4100 Reading Files (3) 120491b.doc Shell Western E&P Inc. 601 West Fifth Avenue · Suite 800 Anchorage, Alaska 99501 April 12, 1991 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Gentlemen- SUBJECT: SUBMISSION OF THE REPORT OF SUNDRY WELL OPERATIONS MIDDLE GROUND SHOAL WELL NO. C13-23 Enclosed in duplicate is the report of Sundry Well Operations for MGS Well No. C13-23. The workover included a Xylene Wash of tubing. Operations were completed March 25, 1991. If you have any questions, please call Ms. Susan Murnan at (907) 263-9614 or Mr. Paul Huckabee at (907) 263-9646. Very Truly Yours, Id. F. Simpson Manager Regulatory Affairs Alaska Division WFS/slm Enclosures AOGCC\SUNDRY.DOC 1. Operations performed: Operation shutdown __ Stimulate__ Plugging__ Perforate__ Pull tubing __ Alter casing__ Repair well __ Other 2. Name of Operator Shell Western E&P Inc 3. Address 601 West Fifth Avenue Suite 800 Anchorage, Alaska 99501 5. Type et Well: Developmen! X Exploratory Stratigraphic Service 4. Location of well at surface At top of productive interval Platform C, Leg 4, Conductor 29. 499'FSL & 1534' FEL of Sec. 23, T8N, R13W, A.S.P. @ 1407' FSL & 4065' FEL Sec. 23, T8N, R13W, SM At effective depth At total depth @ 1480' FSL & 3236' FEL Sec. 23, T8n, R13W '6. Datum elevation (DF or KB) 105'DB feet 7. Unit or Property name Middle Ground Shoal 8. Well Number C13-23 9. Permit number/approval number 88-99/91-089 10. APl number 50-733-20403 11. Field/Pool Middle Ground Shoal/G Pool 12. Present well condition summary Total depth' measured Effective depth: Casing Structural Conductor Surface Intermediate Production Liner true vertical measured true vertical Length 1800 8O34 4493 11,291 feet 9985 feet 11,212 feet 9943 feet Size Plugs (measured) Junk (measured) Cemented 13-3/8", 61#, K-55 BTC 9-5/8", 43.5-47#, N-80 BTC 7", 26-35#, L-80 Measured depth True vertical depth 1012 sx 1800 1734 560 sx 8034 7115 1416 sx 11,921 9985 Perforation depth: measured 9206'-10,278' true vertical 8458'-9341' Tubing (size, grade, and measured depth) 2-7/8", 6.5~, N-80 eue@ 9834' Packers and SSSV (type and measured depth) Baker "DB" Packer @ 9791' I E6EIVED ...... v,~o. t.~UIIIIlII~iUil 13. Stimulation or cement squeeze summary Xylene Wash Tubing Intervals treated (measured) Tubing Treatment description including volumes used and final pressure 550 gallons of Xylene. Vacuum Anchorage 14. Prior to well operation Subsequent to operation Representative Daily Average production 0rln!ection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 368 88 2 640 90 325 70 3 780 90 15. Attachments 116. Status of well classification as: Copies of Logs and Surveys run __ Ii Oil X Gas Suspended Daily Report of Well Operations ~ ~ -- -- 17. I hereby certity that the foregoing ~s true aha correct to the best et my Knowledge Signed Title ~ FP.,41,~ ~ Form 10-404 I~ev 06/15/88 Service Date SUBMIT IN DUPLICATE DAILY REPORT OF OPERATIONS C13-23 March 25, 1991 Halliburton Services rigged up. Pressure test to 4000 psi. Pumped 550 gallons Xylene. Well on vacuum. Return to production. \misc\O40391a Shell Western E&P lnc-0 601 West Fifth Avenue * Suite 800 Anchorage, Alaska 99501 March 14, 1991 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Gentlemen: SUBJECT: SUBMISSION OF THE APPLICATION FOR SUNDRY APPROVALS MIDDLE GROUND SHOAL WELL NO. C13-23 Enclosed in triplicate is the Application for Sundry Approvals for well No. C13-23, Middle Ground Shoal. The surface location is Platform C, Leg 2 Conductor 16. Estimated date for commencing operation is March 15, 1991. If you have any questions regarding this report, please contact Paul Huckabee at (907) 263-9646 or Susan Murnan at (907) 263-9614. Very Truly Yours, R. G. Blackburn Manager, Alaska Operations Alaska Division WFS/wm Enclosure AOGCC.WAM cc: C. M. Kidwell - WCK 1178 B. N. Osborn - Kenai R. R. Wagner - Anchorage P. T. Huckabee - Anchorage S. B. Brown-Maunder - Anchorage V. E. Unger - Anchorage SEC Files - 5.6120 A42-14 Correspondence File - 5.91 Production - WCK 4100 Reading File - Anchorage Reading File - Houston ~--- STATE Of ALASKA Al.a, OIL AND GAS CONSERVATION COMMIS; APPLlCA'IFOR SUNDRY APPFIOVALS 1. Type of Request: Abandon Suspend Alter casing Repair Well Change approved program __ Pull tubing 2. Name of Operator 3. Address Shell Western E&P Inc. 601 West 5th Avenue, Suite 810 Anchorage, AK 99501 OperalJon shutdown Re-enter suspended well Plugging __ Time extension Stimulate Variance Perforate __ Other X 5. [ype et Well: Development X Exploratory Stratigraphic Sen/ice 6. Datum elevation (DF or KB~ 105' KB feel 7. Unit or Property name Middle Ground Shoal 8. Well number 4. Location of well at sudace At top of productive interval At effective depth At total depth Platform C, Leg 4, Conductor 29. 499' FSL & 1534' FEL of Sec. 23, TSN, R13W, A.S.P. @ 1407' FSL and 4065' FEL Sec. 23, T8N, R13W, SM @1480' FSL and 3236' FEL Sec. 23, T8N, R13W 12. Present well condition summary Total depth' measured true vertical Effective depth: measured true vertical C13-23 9. Permit number 88-99 10. APl number 50-733-20403 11. Field/Pool "G" Pool 11291 feet 9985 feet 11,212 feet 9943 feet Plugs (measured) Junk (measured) Casing Length Structural Conductor 1800 Sudace Intermediate 8034 Production 4493 Liner Size 13-3/8", 61#, K-55 BTC 9-5/8", 43.5-47#, N-80 BTC 7", 26-35#, L-80 Pedoration depth: measured 9206'- 10278' true vertical 8458' - 9341' Cemented Measured depth True vertical depth 1012 sx 1800 1734 560 sx 1416 sx 8034 7115 11921 9985 R£ EI VED Tubing (size, grade, and measured depth) 2-7/8", 6.5#, N-80 eue@ 9834 A!~&~ Ojj & Gag C01~$ Packers and SSSV (type and measured depth) Baker "DB" Packer @ 9791' ~rlCJ-lora~ 00~1~11~$$j0~ 13. Attachments Description summaryof proposal X Detailed operations program BOP sketch 14. Estimated date for commencing operation 03/15/91 16. If proposal was verbally approved Oil X Service Name of approver Date approved .____-------..~.~ 17. I hereby~__.., ~ .~ ~ ~certifY that the foregoing is true~q~ correct to the best of my knowledge Signed/~"~ ' /~_~-~-~---~-~-'~ Title Manager Alaska Operations 15. Status of well classification as: Gas Suspended Date 03/14/91 Conditions of approval: Notify Commission so representative may witness Plug integrity BOP Test Location clearance Mechanical Int-~grity Test__ '~Subsequent form requi-'~'d 10- ~'oZi' ORIGINAL SI~NED I~¥ LONNIE C. SMITH ~ o omm~ss~oner Approved by order of the commission ~?nroV~ ©~. ~ ' ' Form 10-403 Rev 06/15/88 ' ' ".Returne(~ I Approval No.q I'-0 ~C'1 SUBMIT IN TRIPLICATE APPLICATION FOR SUNDRY APPROVALS DESCRIPTION SUMMARY OF PROPOSAL MIDDLE GROUND SHOAL WELL No. C13-23 The Middle Ground Shoal well no. C13-23 is currently producing 344 BOPD at a water cut of 0.5%. The production rate has dropped from 424 BOPD in three months indicating a 75% annual decline rate in productivity. The decline in oil rate is expected to be the result of a slickline fish left in the hole from wireline operations in November 1990. Attempts to recover the fish have been unsuccessful to date. We plan to pump 1000 gallons 7-1/2% hydrochloric acid down the tubing to clear suspected scale from around the wireline fish. Subsequent wireline operations will attempt to recover the fish. If the fish cannot be recovered, it is suspected that production will decline sharply from additional scaling restriction in the tubing at the fish. L1 6 7 8 9 10 11 12 13 14 15 16 17 18 COMPLETION EQUIPMENT DETAIL SHEET MGS C13-23 12/12/88 NO. ITEM TBG SLM TVD. MD. PSI OR 1. FLOPETROL SAFETY VALVE 317 2. GAS LIFT MANDREL #1 1700 3. GAS LIFT MANDREL #2 3243 4. GAS LIFT MANDREL #3 4576 5. GAS LIFT MANDREL #4 5688 6. GAS LIFT MANDREL #5 6584 7. GAS LIFT MANDREL #6 7327 8. GAS LIFT MANDREL #7 7932 9. GAS LIFT MANDREL #8 8397 10. GAS LIFT MANDREL #9 8706 iOA. ONE JT TUBING 11. 2-7/8" OTIS "XO" SLIDING SLEEVE 8777 12. ONE JT TUBING 13. BAKER "G" LOCATOR W/ 2 SEAL UNITS, 5' SPACER TUBE, ADD SEAL UNITS & MULESHOE TO UTILIZE AVAILABLE SEAL BORE 8820 14. BAKER "DB" PACKER ID = 3.25" W/ 15' SBE & X-OVER 8820 15. 15' 2-7/8" EUE PUP, TOP @ 8840 16. 2-7/8" OTIS "XN" NIPPLE 8854 17. 8' 2-7/8" EUE PUP 18. OTIS RE-ENTRY GUIDE/SHEAR OUT SUB NO LOWER THAN: 8862 317 1771 899 1/8 3629 938 3/16 5221 935 3/16 6557 930 3/16 7495 923 3/16 8250 972 1/4 8874 952 1/4 9351 938 1/4 9672 OR 5/16 9791 9791 (9762 DI~.'~ 9810 9825 9834 (9805 OIL) CASING 13 3/8", 54.5-61#,K-55, BTC @ 1802' w/962 sx 9 5/8", 43.5-47#, N-80, BTC @ 8034' w/560 sx 7" 26#, L-80, LTC @ 6779 - 9555' 35#, L-80, LTC @ 9555 - 11212' PBTD = 11,212' (LANDING COLLAR), TOPS OF FLAGJOINTS @ 10,331 & 10,559' (D.P.) TD = 11,291' TUBING 2 7/8", 6.5#, N-80, AB-MOD EUE @ 9834' PERFORATED ZONE GR-GS HC-HD HE-HF HI-HK HK-HN HN-HR HR-HZ INTERVAL (DIL DEPTHS), TO BE PERFORATED LATER (TOP OF GR IS @ 9837' (DIL) 10,241-10,268' & 10,272-10,278' 4SPF 2-1/8" ATLAS SILVERJET 10,379-10,416' & 10,420-10,437' 4SPF 2-1/8" ATLAS SILVERJET 10,530-10,541' & 10,545-10,549' 4SPF 2-1/8" ATLAS SILVERJET 10,578-10,668' & 10,674-716 & 10,72D-10,734' 4SPF 2-1/8" ATLAS SILVERJET 10,774-94', 10,828-48', 10,874- 94', 1/2SPF 30 HOLES 10,952-60', 10,968-94', 11010- 22', 11,026-46', 11,074-88' 1/2SPF 40 HOLES PLATFORM "C" MIDDLE GROUND SHOAL CONDUCTOR/WELL SURFACE LOCATIONS LEG 1 Centered 541.65 ft. North and 1596.41 ft. of the SE Corner of Sec. 23, T8N, R13W, SM. CONDUCTOR WELL LEG 2 DISTANCE FROM SE CORNER NORTH WEST 1 C23-23 547.10 1599.00 2 C32-23 547.25 1594.46 3 C34-26 544.25 1591.06 4 C24-26RD 540.57 1590.68 5 C31-26 536.91 1593.01 6 C34-23 535.88 1597.22 7 C23-26 538.03 1600.98 8 C22-26RD 542.18 1602.22 CONDUCTOR LEG 3 9 10 11 12 13 14 15 16 LEG 4 CONDUCTOR 25 26 27 28 29 30 31 32 Centered 618.65 ft. North and 1549.76 ft. of the SE Corner of Sec. 23, T8N, R13W, SM. 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 582.42 ft. North and 1489.90 ft. of the SE Corner of Sec. 23, TSN, R13W, SM. Centered 505.41 ft. North and 1536.56 ft. of the SE Corner of Sec. 23, T8N, R13W, SM. WELL C42-23 C31-23 C43-23 C41-23 C33-26 C-LINE C44-14RD C24-23 DISTANCE FROM SE CORNER NORTH WEST 509.00 1541.00 509.81 1536.57 507.65 1532.61 503.51 1531.56 499.00 1534.44 498.37 1538.72 500.87 1542.26 505.12 1543.10 West DISTANCE FROM CENTER OF LEG N/S E/W 5.45 -2.59 5.60 1.95 2.60 5.35 -1.08 5.73 -4.74 3.40 -5.77 -0.81 -3.62 -4.57 0.53 -5.81 West DISTANCE FROM CENTER OF LEG N/S E/W 5.00 -2.90 5.50 1.40 4.00 5.00 -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 [ FOD[LAIIO LIGHT · Zyf;6o. .re, · · LO~TtON ~A.$. PL~TFOftM COOK INLET ,'~ Sc~Lr I', '200Q' Ido~c~ Please sign and return this card to ATLAS WlRELINE THISISTOACKNOWLEDGERECEIPTOFTHEFOLLOWINGWELLLOGSANDNEGS: FOR ATLAS WIRELINE SERVICES ATTENTION LARRY GRANT AT STATE OF ALASKA, ALASKA OIL & GAS COMMISSION WELL MGS C13-23, MGS C24A-14, MGS C24A-23 MGS C21-23 PRODUCTION LOGGING 8/30 1 PRODUCTION LOGGING 9/2 1 PRODUCTION LOGGING 9/3 1 PRODUCTION LOGGING 9/4 1 I~L~.L.I Y i., I,/ OCT 2. 2. 1'990 SIGNED __PRINTS~NEG. 1 SEPIA __PRINTS~NEG. ,, 1 SEPIA __PRINTS~NEG. 1 SEPIA __PRINTS~NEG. 1 SEPIA ~PRINTS~NEG.~SEPIA ~PRINTS~NEG.~SEPIA __PRINTS~NEG.~SEPIA ~PRINTS~NEG.~SEPIA DATE 19.__ RETAIN THIS SECTION FOR YOUR RECORDS RE MGS C13-23. MGS C24A-14. MGS C24A-23. PRODUCTIONLOGGING 8 / 30 1 PRINTS ~ PRODUCTION LOGGING, 9/2 1 P. BINTS PRODUCTION LOGGING ~.~4~'' TS . --,-RRINTS ABOVE RECEIVED FROM: ATLAS WIRELINE MGS C21-23 NEG. NEG. NEG. NEG. NEG. NEG. NEG. NEG ...... SEPIA SEPIA SEPIA . SEPIA SEPIA SEPIA SEPIA ..... SEPIA ATTENTION LARRY GRANT SIGNED DATE 19__ 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 300] Porcupine Drive Anchorage, Alaska 99501 L 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: 2 location surveys showing the location of Platform A 1 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 1 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. If you have any further questions regarding these matters, please continue to contact Susan Brown-Maunder at (907) 263-9613. Very Truly/Yours, W. Ir. Simpson Manager, Regulatory Affairs Alaska Division WFS/SBBM/vj Enclosures cc: Susan Elsenbast-AOGCC \LETTERS\AOGCC\061190. DOC RECEIVED Alaska Oil.& Gas Cong. Comn~f~:~O!I Anchorag3 Shell Western E&P Inc. Q 601 West Fifth Avenue · Suite 810 Anchorage, Alaska 99501 April 17, 1989 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Gentlemen: SUBJECT: SUBMISSION OF WELL COMPLETION OR RECOMPLETION REPORT AND LOG FOR WELL C13-23 Enclosed, in duplicate, is the Well Completion or Recompletion Report and Log for Well C13-23. If you have any questions, please call Ms. Susan Brown-Maunder at (907) 276-2545. Very truly yours, W. F. Simpson Manager Regulatory Affairs WFS/SBBM/raf Enclosures SBB I / aogcc. 040489 ..... STATE OF ALASKA ..... ALASKA Oi_ AND GAS CONSERVATION COk .... ISSION WELL'COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number She] l Western E&P Inc. 88-99 3. Address 8. APl Number 601 West Fifth Avenue, Suite 810, Anchorage, Alaska 99501 50- 733-20403 4. Location of well at surface Platform C, Leg 2, Conductor 16, 9. Unit or Lease Name 618.65' FSL, 1549.76' FEL SEC 23, T8N, R13W, SM Middle Ground Shoal At Top Producing Interval ~1407' FSL and 4065' FEL SEC 23, T8N, R13W 10. Well Number 613-23 At Total Depth (~1480' FSL and 3236' FEL Sec. 23, T8N, R13W ll. FieldandPool , , 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Middle Ground Shoe] 105' KB ADL 18756 "E F & G" Pool ¢ _ 12. Date Spudded08/28/88 13, Date T.D. Reached10/7/88 14. Date Comp., Susp. or Aband.11/22/88 I15' Water Depth' if °ffsh°re73 ' feet MS L,_~ 6. No. of Completionss i ng] e 17. Total Depth (~I'D+TvD) 18.Plug Back Depth (MEH-TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 11,291' + 9,985' 11,212' + 9,9.43' YESE~ NoEl 317' feetMD None 22. Tvpe Electric or Other Logs Run D ITE/LSS/GR/SP/LDT/AMS/CBL/CCL/GR/GYRO '~3. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 13-3/8" 61# K-55 BTC' 0' 1,800' 17-1/2" 1012 sx Class "G" + Addit ve 0' 9-5/8" 43.5-47# N-80 BTC 0' 8,034' 12-1/4" 560 sx Class "G" + Addit ve 0' 7" 26-35# L-80 6,768' 11,291' 8-1/2" 1416 sx Class "G" + Addit ve 0' , 24. Perforations open to Production (MD?TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 2-7/8",6.5#,N- 10 9,834' 9,791' (Drill Pipe) SEE ATTACHED COMPLETION EQUIPMENT DETAIL SHEET ~6. ACID, FRAcTuRE, CEMENT SQUEEZE, ETC. ,, , D_~PTH INTERVAL (MDi A'MOUNT& KIND OF MATERIAL USED 10,952'-11,088'(40H] 586 bbls, Tot,a] proppant;8200# 20-40 mesh carbolite ~0,7'74'-10,894'(30H) 1267 bb]s~ Tote] proppant;60000# # cerbo]ite 20/40 mesh : , 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) 11/22/88 11 Gas Lift Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO 11/22/88 24 TEST PERIOD I~ 778 206 4 128 265 · . Flow Tubing Casing Pressure cALCULATED__~. OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 100 820 24-HOUR RATE I~ ......... 35.1 . 28. CORE DATA , Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None ~EcEIV' ED Cons. , · ~l~sl'~ 0il & Anchorage , Form 10-407 Rev. 7-1-80 SBBI/wcr,C13-23 CONTINUED ON REVERSE SIDE Submit in duplicate 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. , N/A N/A RECEIVED APR 1 8 1989 Alaska.Oil & Gas Cons. Commission '' ,~ch0rage , 31. LIST OF ATTACHMENTS D~i]y Eeport of 0perat~ons~ Comp]etion Equipment: Detail Sheet~ 32. I hereby ce~best of my knowledge ~ Signed Title D'iv. 0pr'Fis. Ngr. Date, INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27' Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". SBBI/wcr.C13-23 Form 1 6 7 8 9 10 11 12 13 " 15 16 17 18 COMPLETION EQUIPF'IENT DETAIL StlEET MGS C13-23 12/12/88 NO. ITEM TBG SLM 'I"VD . MD. PSI OR 1. FLOPETROL SAFETY VALVE 2. GAS LIFT MANDREL #1 3. GAS LIFT MANDREL 4. GAS LIFT MANDREL #3 5. GAS LIFT MANDREL #4 6. GAS LIFT MANDREL #5 7. GAS LIFT MANDREL fl6 8. GAS LIFT MANDREL #7 9. GAS LIFT MANDREL #8 10. GAS LIFT MANDREL #9 ZOA. ONE JT TUBING 11. 2-7/8" OTIS "XO" SLIDING SLEEVE 12. ONE JT TUBING 13. BAKER "G" LOCATOR W/ 2 SEAL UNITS, 5' SPACER TUBE, ADD SEAL UNITS & MULESHOE TO UTILIZE AVAILABLE SEAL BORE 8820 14. BAKER "DB" PACKER ID = 3.25" W/ 15' SBE & X-OVER 8820 15. 15' 2-7/8" EUE PUP, TOP @ 8840 16. 2-7/8" OTIS "XN" NIPPLE 8854 17. 8' 2-7/8" EUE PUP 18. OTIS RE-ENTRY GUIDE/SHEAR OUT SUB NO LONER THAN: 8862 317 1700 3243 4576 5688 6584 7327 7932 8397 8706 8777 317 1771 899 1/8 3629 938 3/16 5221 935 3/16 6557 93O 3/16 7495 923 3/16 8250 972 1/4 8874 952 1/4 9351 938 1/4 9672 OR 5/16 9746 9791 9791 (9762 DIL) 9810 9825 9834 (9805 DIL) CASING 13 3/8", 54.5-61#,K-55, BTC @ 1802' w/962 sx 9 5/8", 43.5-47#, N-80, BTC @ 8034' w/560 sx 7" 26#, L-80, LTC @ 6779 - 9555' 35#, L-80, LTC @ 9555 - 11212' PBTD = 11,212' (LANDING COLLAR), TOPS OF FLAGJOINTS TD : 11,291' L.' TUBING APR 1 8 ]989 2 7/8", 6.5#, N-80, AB-MOD EUE@ 9834' ?!'~;'?;!: .... .;;&i~.l~gC:-~.;.CL,..:?~;~js.s~a,,t PERFORATED ZONE INTERVAL (DIL DEPTHS) GR-GS HC-HD HE-HF HI-HK HK-HN HN-HR HR-HZ TO BE PERFORATED LATER (TOP OF GR IS @ 9837' (DIL) 10,241-10,268' & 10,272-10,278' 4SPF 2-1/8" ATLAS SILVERJET 10,379-10,416' & 10,420-10,437' 4SPF 2-1/8" ATLAS SILVERJET 10,530-10,54'1' & 10,545-10,549' 4SPF 2-1/8" ATLAS SILVERJET 10,578-10,668' & 10,674-716 & 10,720-10,734' 4SPF 2-1/8" ATLAS SILVERJET 10,774-94', 10,828-48', 10,874- 94', 1/2SPF 30 HOLES 10,952-60', 10,968-94', 11010- 22', 11,026-46', 11,074-88' DAILY REPORT OF OPERATIONS C13-23 DATE o8/28/88 08/29/88 08/30/88 08/31/88 09/01/88 DESCRIPTION Rigging up. Clean out flowline. Install 10" Diverter Line/Valves. M/U 17.5" bit and cleaned out assembly. Tagged fill at 361'. Spud well at 0800 hrs. Adjust Diverter Valves. Function test. Circ hole clean. POH, make up mud motor/MWD assembly. Drilling F/658' T/869'. Running Gyro. Drilling Gyro to 1319' W/2RR bit. Circ/Cond F/Trip. POH, lay down mud motor, make up angle building assembly, tripping in hole. Layed down 6 joints, drill pipe and ream tight hole to 1300'. Drilling to 1509' W/Bit #3. Drilling to 1784' W/Bit #3. Drilling to 1800' W/Bit #3. Circ/Cond F/Csg. POH. Rig ran 45 .its. of 13.375" 54.5# (From 986 to 1800' then 61# 473' to 986' then 54.5# surface to 473'.) to 986' then 54.5# surface to 473'.) All csg. is K-55 BT&C R-3. 1802' "On Hook". Baker float shoe at 1800', (KB) and Baker Float Collar at 1755'. Installed baker model "M" cent's at 10' 40' 80' 120' 200' 360' Bottom 7 its are baker-loc'ed. Tested annular/diverter system on shoe jr. OK. Checked Float Equip. OK. Fill each jr. as ran. Went to bottom ok, no fill. Circ/Cond for cement job. Test lines T/3000#. OK. Drop BTM plug, pumped 50 bbls. fresh water ahead of 762 SX class "G" Cmt. + 10% GEL + 2% CaC12 + .5% CFR-3. Wt. 12.8 PPG, 11.5 Gal/SX mix water, 2.08 yield. Tailed w/200 SX Class "G" CMT + 2% CaC12 + .5% CFR-3. 15.8 PPG., 4.96 GAL/SX Mix Water, 1.15 yield drop lOP plug, displaced W#/275 bbls mud at 7-8 bbls/min rate. Had full Ret's throughout job. Had CMT T/surface, Est. 70 bbls. bumped plug, Float held. CIP at 2130 hrs. W.O.C. tear out Howco. Rigging Down 10" Diverter system. Nipple down 20" annular preventor. Weld in gussetts between 13.375" csg. and the 24" conductor just below floor level. Made final cut on csg. weld on SOW. Test T/800# F/20 mins. OK. Nipple up BOPE. Test BOPE. Had verbal approval to set 13.375" csg. at 1800' vs 2376'. Making up "locked-up" BHA and going in hole. Wear Bushing is in place. SBBI/102188 I DAILY REPORT OF OPERATIONS (continued) C13-23 DATE 09/02/88 09/03/88 09/04/88 09/05/88 09/06/88 09/07/88 09/08/88 09/09/88 09/10/88 09/11/88 DESCRIPTION RIH T/1750' Test Csg. Ia 1500 PSI, Drill float equipment, ~rill 12 1/4" hole to 1826', test formation leak off at 13.0 PPG equivalent. Drill 12 1/4" hole to 2826' Make short trip, POOH to casing shoe. Drill to 3]~9'. Drill and survey to 3885'. Short trip to 13 3/8" csg. shoe. Drill and survey to 4313'. 5 rotational survey check, mix pill. Check flow, pump pill, POOH. L/D stab, M/U Bit #5, RIH T/csg/ shoe, fill pipe. Slip and cut 100' drill line. RIH T/4313' Drill and survey to 5052'. Check flow, pump pili. POOH. POOH with Bit #5. M/U Bit #6, P/U Stab, RIH T/csg shoe, fill pipe, test MWD. RIH T/5052'. Drill and survey to 5521'. Short trip 10 Stds. Drill and Survey to 5680'. Drill and survey to 6019'. Survey, check for flow, pump pill. POOH, lay down lead collar. P/U Bit #7, P/U Monel Collar W/clamp on stab., RIH T/csg. shoe. Repair swivel packing in Kelly. RIH T/6019'. Drill and survey to 6185'. Drill and survey to 6459'. Short trip 10 stds. Drill and survey to 6613'. Drill and survey to 6621'. Check flow, pump pill, POOH. Change monel collar, M/U bit #8 RIH. Check MWD, RIH T/csg. shoe, fill pipe, RIH T/6621'. Drill and survey to 6911'. Drill and.survey to 7115' Check Flow, pump pill, POOH. Test choke manifol~ @ 250/3000 PSI. Test Annular Preventor ~250/3000 PSI. Retrieve test plug, install BOPE protector. Drill to 7160'. Drill 12 1/4" hole to 7674'. MWD failed at 7157', received verbal waiver from Mike Minder, AOGCC, 09/10/88 to drill until bit dulls without taking survey. Single shot survey will be taken at end of bit run. Drill to 7679'. Test MWD, RIH to 7619'. Drill to 7874'. SBBI/102188 2 DAILY REPORT OF OPERATIONS {continued) C13-23 DATE 09/12/88 09/13/88 09/14/88 09/15/88 09/16/88 DESCRIPTION Drill and survey to 8045'. Make 15 std. short trip. Circ. and cond. for logs. POOH for logs. L/D MWD, L/D jars. Rig up schl. RIH W/DIT/GR to 3000', tool failed, POOH. Reached csg. point at 1850 hrs. Log W/schlum. AMS/DIT/GR log. Rig down schlum. Retrieve bore protector, change pipe rams to 9.625" casing rams, install test plug, test bop bonnet seal @ 250/3000 PSI., retrieve test plug. Rig up casing handling tools and equipment. Rig up to run 9.625" casing. P/U and run 193 jts. 9.625" 43.5# and 47# N-80 BTC casing, start losing returns at 2675', partial returns (25%) for remainder of casing job. RIH to 8034'. float shoe at 8034', float collar at 7951'. M/U circ Swedge, attempt to break circ. at 3 BPM with 450 P~I, lose at rate of i BPM., make up HOWCO cement head, rig up cmt. lines. Test cmt. lines at 250/3000 PSI. Pump 100 bbls fresh water ahead. Mix and pump 360 SX "G" + 1.5% Gel + 0.4% CFR-3 mixed at 14.2 PPG followed by 200 SX "G" + 0.5% CFR-3 + 0.1% HR-7 mixed at 15.8 PPG, displace with 588 bbls 9.2 PPG mud at 8 BPM, 400 PSI, partial returns during displacement, bump plug with 1500 PSI, cement in place. Nipple down riser, set "AW" slips on 9 5/8" casing with 325 M weight on slips, cut off casing, N/U "AP" spool, DSA and riser, test wellhead @ 1300 PSI, install test plug, test rope: test all lines, valves, rams at 250/5000 PSI, test annular preventer at 250/3500 PSI, test choke manifold at 250/5000 PSI. RIH, fill pipe at 4000', tag CMT at 7944'. Drill CMT and float equipment to 7985'. Test casing at 3000 PSI for 30 minutes. Drill CMT and float equipment at 8034' Drill 8.5" hole to 8145', (Drill first foot ~.5" hole at 0130 hrs. 9/14/88.) Test formation leak off. (17.0 PPG equivalent) Notified AOGCC of BOPE test. Received verbal waiver from Mike Minder to waive witness. Drill and survey to 8585'. Drill to 8596'. POOH. RIH to 8000'. Slip and cut 100' of drilling line. RIH to 8596'. Drill and survey to 8850'. SBBI/102188 3 DAILY REPORT OF OPERATIONS (continued) C13-23 DATE 09/18/88 09/19/88 09/20/88 09/21/88 09/22/88 09/23/88 DESCRIPTION Drill and survey to 9458'. Check for flow, survey, pump dry job, POOH. Change BHA. Trip in Hole. Ream from 9409' to 9458'. Drill to 9522'. Drop survey, pull to shoe, RIH w/wireline and retrieve survey, RIH. Drill to 9613'. Drop survey, pull to shoe, RIH w/wireline and retreive survey, RIH. Drill to 9685'. Drill to 9796'. Stuck drilling assembly at 9796'. Jar on stuck pipe, had decline in pump pressure. Determined washout. Worked left hand torque downhole, had back off, P/U 340,000#. POOH looking for washout, found washout in stand 54. Recovered drill pipe, HWDP and top set of jars (up). Tools left in Hole, DN Jar, 1-JT. SWDP, XO, DC, NM Stab, 7-MC. Bit sub and RBI bit C15 SNAZ333, total length 182.02'. Top of fish at 9613.98'. Making up clean out assembly. Complete making up BHA, RIH to shoe at 8034' Slip and cut drilling line 100' RIH to top of FiSH at 9613' Circ hole clean. ~OOH. Pick up 13 its. of 3 1/2G tubing for cement stinger. RIH. Break circ at 4500' Pick up 30 jts. of S135, RIH to 9612'. Pump 20 ~BL. gel pill on top of fish. Pull 1-stand, rig up and test Howco lines to 3000 PSI. Pump 50 bbls of water W/1% NaC1 ( 20 BBLS), 1% NACL W/7#/BBL Caustic (20 BBL) 1% NaC1 (10 BBL) followed by 200 SX of class "G" cement + 0.5% CFR-3 + 1% NaC1. 16.7 PPG, 4.0 Gal/SK, 1.02 CF/SK. Displaced W/20 BBLS of NaC1 followed by 135 BBLS. of mud. Pulled 10 stands, drop plug, shear out at 2000 PSI. POOH, lay down 30 joints of S135. Lay down 13 its. of 3 1/2" tubing. Test BOPE. Continue test BOP£. Test all lines, valves, rams at 250/5000 PSI. Test Annular Preventer at 250/3500 PSI. Test choke manifold at 250/5000 PSI. Inspect shop and HWDP. RIH to shoe. Circ and wait on cement. RIH tag green cement at 9012' Drill green cement to 9251'. Circ out contaminate~ cement. Drill green cement to 9281', circ clean. Pull to shoe. Wait on cement. WOC. RIH to 9281'. Drill Cement to 9342', hard cement at 9320'. Circ clean. POOH. M/U mud motor and kick off assembly. RIH. Orient Tool. Drill W/mud motor, to 9420'. SBBI/102188 4 DAILY REPORT OF OPERATIONS {continued) C13-23 DATE 09/23/88 09/24/88 09/25/88 09/26/88 09/27/88 09/28/88 09/29/88 09/30/88 10/01/88 DESCRIPTION WOC. RIH to 9281'. Drill Cement to 9342' hard cement at 9320'. Circ clean. POOH. M/U ~ud motor and kick off assembly. RIH. Orient Tool. Drill W/mud motor, to 9420' · Drill to 9426' W/ mud motor. POOH. Change out BHA. RIH to shoe. Cut and slip 100' drilling line. RIH. Ream to 9426'. Drill to 9546'. Drill to 9586'. Make 5 std. short trip. Drop survey, pull to shoe, retrieve survey. RIH. Drill to 9678' Drop survey, POOH. Change out bit. RIH. Drill to 9705'. Circ aireated mud. Drill to 9770' · Short trip 5 stands. Drill to 9790'. Work through coat to 9798'. Drill to 9830'. Drop survey, POOH, lay down 30 j ts. of S135 pipe. Change out bit and BHA. RIH. Pick up 30 its. of G pipe. Ream to 9830'. Drill to 9929'. Work through coat to 9939'. Drill to 9957'. Run single shot on wireline. Drill to 10081'. Short trip 5 stands. Drill to 10110' Run single shoot on wireline. Pump pill, POOH. Rill to shoe. Slip and cut drilling line at report time. RIH to 10110'_. Drill to 10233'. Run single shot on wireline. ,Drill to 10322'. Short trip 5 stands. Drill to 10385 . Run single shot on wireline. Dril~ to 10475'. Drop survey, pump pil). POOH to 9297 . Work through tight spot to 9270 POOH, lay down steel DC. Test BOPE, test all lines, valves, rams at 250/5000 PSI, test Annular Preventer at 250/3500 PSI, test choke manifold at 250/5000 PSI. Change BHA, pick up new bit. RIH, fill pipe at 4000' and 8000', P/U 12 jts. of G pipe. P.U kelly and clean out bridge 10185' to 10200', 10392' to 10475'. Drill to 10495'. Drill to 10597'. Wireline survey at 10597' Drill to 10729'. Drop survey, pump pill, POOH. ~etrieve survey. Change bits. RIH to 10729', fill pipe at 4000' and 8000'. Drill to 10778'. Wireline survey at 10778'. Drill to 10990'. SBBI/102188 5 DATE 10/02/88 10/03/88 10/04/88 10/05/88 10/06/88 DAILY REPORT OF OPERATIONS (continued) C13-23 DESCRIPTION RECEIVE APR 1 8 ]989 Drill to 11026' Check for flow, drop survey, pump pill. POOH, chJnge BHA, M/U bit #23. RIH w/bit //23, fill pipe at 4000' and 8000'. Slip and cut 100' drilling line. RIH to 10880', hit bridge. Ream to 11026'. Drill to 11137'. Drill to 11221'. Check flow, POOH 15 stands to 9817' for short trip, TIH. Circ. and cond. for logs. Check flow, drop survey, pump pill. POOH with bit //23, SLM. P.U kelly and work through tight spot at 8818'. POOH, SLM. Rig up Schlumberger, make up DITE/LSS/AMS/GR/SP log, tool power supply failed. Trouble shoot Schlumberger equipment at report time. RIH W/SCHL. to 11190', log W/SCHL. Dite/LSS/GR/AMS. POOH. L/D Dite, M/U LDT/GR/AMS, RIH to 11094', log to 10700', stuck tools. Attempt to free stuck tools, prepare to cut line and strip over line. Cut line, M/U tri-state overshot, RIH strip over SCHL. line. RIH strip over wireline to 11677'. Install SCHL. Circ. Sub, Hang line, rig up circ. head, circ. bottoms up. Rig down circ. head, attempt to work overshot down over top of fish at 11715'. Drive chain on SCHL. Cable spool broke. Repair drive chain, adjust brakes. Install SCHL. Circ. sub, circ. head, check pump rate and pressure for indication of fish in overshot, O.K., rig down circ. head, attempt to work overshot over fish again. Rig up SCHL. T-Bar clamp, pull out of rope socket with rig blocks. POOH. W/SCHL. wireline. POOH, work tight spots at 10500' and 9450'. Recover 38' SCHL. logging tools, (full recovery, undamaged) lay down SCHL. LDT/GR/AMS, lay down tri-state fishing tools. Rig up dia-log casing caliper, calibrate same. RIH W/casing caliper to 8000', tool not opening. POOH. Recalibrate tool, RIH W/casing Caliper to 8000', log 9 5/8" casing to surface. Rig down dia-log. Retrieve wear bushing, install test plug, test BOPE, test all rams, choke manifold valves and lines, lines, valves, ~250/5000 PSI, test Annular Preventer @ 250/3500 PSI. Install wear bushing. L/D spiral weight drill pipe. M/U BHA. TIH W/bit //24, hit bridge at 10800'. Wash and ream to 11221' Drill to 11291'. 'POOH for wiper trip, POOH 9 stands SBBI/102188 6 DAILY REPORT OF OPERATIONS (continued) C13-23 DATE 10/08/88 10/09/88 DESCRIPTION running tool, RIH W/liner with full returns, set 7" liner shoe Ca 11291', float collar La 11250', landing collar La 11212'. Make up brown cement head and cement manifold. Circ. and cond. for cement job, clean pits, mix cement mix water, rig up howco cement lines. Drop ball to set liner hanger, circulate same down, pressure up to 1800 PSI, set liner hanger La 67876', top of tie back sleeve La 6768' Sheer out W/2900 PSI. Rotate and release from i iner. Pump 50 BBLS fresh water + 1% NaC1 ahead, test cement lines ca 5000 PSI. Mix and pump 1415 SX "G" + 0.2% CFR-3 + 1% NACL + 0.5% HALAD 344 + 0.08% LWL mixed La 15.6 PPG, drop drill pipe wiper plug. Displace W/289 BBLS 11.0 PPG mud ca 10 BPM ca 1300 PSI, did not bump plug, check floats, (O.K.) cement in place La 00:40 10/07/88. Full returns during cement job. Rig down brown cement head, POOH 20 Stds to 4908' Reverse Circ. I 1/2" drill pipe volume ino cementi. Shut well with 300 PSI on Annulus. Well shut in, WOC, (pressure bled off to 50 PSI). POOH, L/D baker setting tool. Service rig. L/D 8.5" stabilizers. M/U 8.5" bit, casing scraper, BHA. TIH to top of tie back sleeve at 6768', no cement. Circ. bottoms up (no cement). POOH to 6675', close rams, test casing/liner lap at 3000 PSI for 30 min. Test O.K. POOH, L/D 15 SWDP and JARS. P/U Howco inflow test tools, RIH to 2881', fill pipe W/11.0 PPG mud, RIH to 6670'. Set Howco RTTS Packer Ca 6670', open hydra spring valve, test liner lap W/2000 PSI drawdown. Open dual CIP valve, equalize well. Reverse Circ., pump pill. POOH, L/D 120 JTS 5" drill pipe. L/D Howco inflow test tools, read pressure bomb charts, no inflow. P/U 6 4.75" drill collars, CSG scraper, 5.875' bit. Make up BHA at report time. P/U 4.75" drill collars, BHA. RIH, P/U 138 Jts. 3.5" drill pipe. TIH W/5" drill pipe, (SIM) tag cement La11035'. Drill cement to 11055' Circ. contaminated mud. Drill Cement to 1121~'. tag landing collar at 11212'. Circ. out cement. Close Rams, pressure test casing to 3000 PSI for 30 min. test O.K. POOH. RIH, finish P/U 3.5" drill pipe. SBBI/102188 7 DATE 10/10/88 10/11/88 10/12/88 10/13/88 DAILY REPORT OF OPERATIONS (continued) C13-23 DESCRIPTION P/U 3.5" drill pipe. Mix and pump pill. POOH W/3.5" drill pipe. R/U Dresser Atlas wireline, test lubricator Ca 1000 PSI. RIH W/Dresser Atlas CCL/GR/CBL, run cable with 1000 PSI on Annulus. L/D Dresser Atlas CCL/GR/CBL. M/U Gyro data Gyro tool. RIH W/Gyro to 10580'. tool failed, POOH. Change out Gyro data tool. Change out Gyro tool. RIH with Gyro to 10583', POOH, make sets Ca 100' intervals. POOH, L/D Gyro, R/D Dresser Atlas wireline. RIH W/5" drill pipe. POOH, L/D 216 Jts. 5" drill pipe. L/D 6.5" drill collars and excess pipe in Derrick. Rig up 3.5" tubing handling tools, strap 3.5" 9.3# N80 AB Mod tubing. M/U 5.875" bit, casing scraper, D.C.'s, RIH P/U 3.5" 9.3# N80 AB mod tubing. Drift all tubing to 2.8". P/U 3.5" 9.3# N-80 AB mod tubing to 11188'. R/U shell slick line unit. Circ. I tubing volume. R/U Sperry Sun Gyro. Orient tool. RIH W/Gyro to 11181', survey ca 100' stations to 10000', POH, R/D Sperry, R/D Sl ickline unit. Clean mud sysem, clean pits, suction lines, etc. Reverse Circ., Displace 11.0 PPG mud W/filtered injection water. Circ. 200 BBLS filtered injection down tubing, reverse circ. 200 BBLS injection water, reverse circ. 50 BBLS injection water + 1/2 drum cabot cleaner X-166, reverse circ. 80 BBLS injection water + 1.5#/BBL HEC + 50#/BBL coarse nut l~, reverse circ. 50 BBLS injection water + 1/2 ~h~um cabot cleaner X-166, reverse circ. injection water. Catch pills in pit and rig up to pump to production fcilities. Pump 230 BBLS Cabott cleaner X-166 pill to production, notified lease operator at Onshore of ETA of pill. Clean pits. Filter injection water with 3 micron cartridge filter skid; displace injection water filtered injection water. Filter injection water T/3 micron, reverse circ. and displace same. POOH with tubing. Retrieve bore protector, install test plug, test BOPE: Test all rams, HCR Valve, manual valves, kill line valves, choke manifold valves, Kelly valves, safety valves and lines Ca250/5000 PSI, test Annular Preventor Ca 250/3500 PSI. All test good. Retrieve test plug, install bore protector. Make up mule shoe, PUP Jr., RTTS Packer, Circ. Valve, XN nipple, XO, RIH W/3.5" Frac string to 10445'. Set RTTS Packer Ca 10445', rig up to test tubing and casing. Set up Dowell Frac equipment on deck. SBBI/102188 ~ DAILY REPORT OF OPERATIONS (continued) C13-23 DATE 10/14/88 10/15/88 10/16/88 DESCRIPTION protector, install test plug, test BOPE: Test all rams, HCR Valve, manual valves, kill line valves, choke manifold valves, Kelly valves, safety valves and lines @250/5000 PSI, test Annular Preventor @ 250/3500 PSI. All test good. Retrieve test plug, install bore protector. Make up mule shoe, PUP Jt., RTTS Packer, Circ. Valve, XN nipple, XO, RIH W/3.5" Frac string to 10445'. Set RTTS Packer @ 10445', rig up to test tubing and casing. Set up Dowell Frac equipment on deck. Test Annulus to 3000 PSI, O.K. Test tubing to 4000 PSI, O.K. Rig up Dowell-Schlumberger's head/lines, rig up Dresser-Atlas wireline. Run #1, 11074-11088, misfired Run #2, 11074-11088, surface PSI went to 20 PSI, all fired. Run #3, 11026-11046, Surface PSI 10 to 20 all fired. Run #4, 11010-11022 and 10952-10960, Surf PSI 10-20. All fired. Run #5, 10968-10994, Surface still 10-20 PSI, POH W/gun. All guns were 2 1/8" Bar Guns, loaded with I JS every other ft. total shots was 40. Lubricator was tested to 3500 PSI, O.K. Finish POH W/run #5. All fired. Rig down Dresser-Atlas. Rigging up Dowell for mini-frac. Filled lines for pressure test, #1 turbine had starter failure. BBL/MIN counters failed. (Electronic Problem) got starter repaired, still working on electrical problem. The PSI is 10#. Finish repairs to Dowell Data Acquisition unit. Pressure test Dowell surface lines to 10000 PSI. Fix small leaks. O.K. Perform Acid Ballout with 24 BBL of 15% HCL and 60 balls. Pumped 5 BBL/MN Max, very little ball action, surged off balls. Rig up Dresser-Atlas wireline for downhole pressure measurement during injectivity test. Had electrical short in line. Cut 450' line off and rehead. High pressure recording tool failed going in the hole. POH and replaced tool. Lubricator packoff failed when back on bottom, POH and repaired. RIH to 11161'. Prefrac formation breakdown. 8.6 BBL/min at max surface PSI of 8600#. POH W/Atlas downhole tools. Repeat breakdown W/slick water (10#/1000 gal HPG Gel) to reduce friction. Max rate 18.9 BBL/Min SBBI/102188 9 DAILY REPORT OF OPERATIONS (continued) C13-23 DATE 10/17/88 10/18/88 10/19/88 DESCRIPTION at 10,000 PSI. Estimated ISIP=6900 PSI at surface, 11200 PSI downhole. (1.1. PSI fracture gradient) repeated breakdown with 42 BBLS. of slick water. Last attempt to create a fracture: Pumped 100 BBLS premixed GEL W/adomite and 0.6 #/Gal 100 mesh sand followed by 110 BBLS of slick water at an average rate of 16.9 BPM. Max PSI 9800#. When the sand reached perfs, pressure increased about 200 PSI? (From about 9600 PSI). Evaluate injectivity test and design fracture job. Refill Frac tanks; preparing for frac job. Tear out Dresser-Atlas. Gelled up two 500 BBL. Frac Tanks. mixed up the Adomite Regain (fluid loss additive) in one of the 500 BBL tanks to be used for pad and prepare for frac treatment. Test lines to 10000 PSI. o.k. Attempt to fracture treat HR-HZ. Surface injection pressure peaked at 9400 PSI at 16 BPM and dropped back to some 8500 PSI at 16-18 BPM. Injected the following: Stage 1; 52 BBLS cross-linked GEL. Stage 2; 25 BBLS cross-linked GEL W/I#/GAL 100 mesh sand. Stage 3; 35 BBLS GEL Stage 4; 27 BBLS GEL W/2#/GAL 100 Mesh Sand. Stage 5; 35 BBLS clean Gel. Stage 6; 26 BBLS GEL/I#/GAL 20/40 Carbolite Proppant. Stage 7; 34 BBLS clean Gel. Stage 8; 52 BBLS GE1W/1.4#/GAL 100 mesh. Stage 9; 26 BBLS GEL. Stage 10; 102 BBLS W/1.3#/GAL Proppant (15 BPM @ 9100 PSI). Stage 11; 67 BBLS GEL W/2.2#/GAL Proppant. (14.7 BPM @ 9760 PSI) then 105 BBLS of Gel Flush to Perfs. Left well shut in for 5 hrs. pressure was down to 3400 PSI after 5 hrs. Back- flowing Well; .5 BBLS min for first 2 hrs then I BBL min rate for .5 hrs. PSI down to test SEP PSI (60#) shutin for PSI build up. Had 1000# in 15 mins and 1600# in 1.5 hrs. continue to back-flow well to test Sep; 7 BBLS/Hr Rate at 60 PSI. Recovered 57 total BBLS. (About 1/2 of the TBG Volume.) Backflow well to test Sep. Shut well in for pressure build up, had 1000# in 1 hr. Backflow well to test sep. (Wt. up pits T/9.6 PPG with salt). Shut in for build up. Had 825# in I hr. preparing for kill. Finish preparations for kill. Reverse Circ. 650 BBLS of 9.5 PPG taking returns to production sep's. Had slight flow, Circ conventional one circulation and wt. up to 9.6 PPG. POH, lay down RTTS. Make up mule shoe on end of tubing, TIH, tag sand at 11150'. SBBI/102188 10 DAILY REPORT OF OPERATIONS (continued) C13-23 DATE 10/20/88 10/21/88 10/22/88 DESCRIPTION POH to 10900'. Rig up HOWCO, test lines to 3000# O.K. Mix/Pump 52 sx of 20-40 sand for a plug on t~p of the HR-HZ. Wait for sand to settle. Tag sand at 10906, TBG measurement. POH for RTTS. Did weekly rope test. Make up RTTS, TIH, changed all seal rings in TBG couplings as ran. Set RTTS at 10259' with tail at 10272'. TBG measurement. Test Annulas to 3000 psi and Tubing to 4000 psi o.k. Rig up Dresser-Atlas, test lubricator to 3500' psi. O.K. RIH with gun #1. Tag bridge at 10849' preventing perforating 10874 - 10894' POH with gun, rig down atlas. SLM out with RTTS. Finish SLM out with RTTS. No correction. TIH with mule shoe on EIT. Tagged sand at 10897' tubing measurement. Pulled seven stands up to 10210'. Above top 7" casing flag joint at 10300'. Rig up Dresser-Atlas wireline, test lubricator to 3500 psi. O.K. Run in hole with collar locator, correlate with tubing depth, 40' difference. POH with wireline, rig down Atlas. Run in to top of sand, reverse out to 10962' (tubing measurement). This is to 10922' wireline measurement for perforating information. Pulled up 8 stands to 10210' again. Rig up Dresser-Atlas, test lubricator to 3500 psi, O.K. run in hole, tagged sand at 10922' (WIM) logged to EOT for correlation. POH with wireline, rig down Atlas. POH with mule shoe. TIH with RTTS. Set RTTS Packer at 10259', with tail at 10272' Tubing measurement. Test Annulus to 3000#, Tu~ing to 4000# O.K. RU and test Dresser Atlas lubricator to 3500#. PREP to PERF HN-HR. RIH with gun #1, from 10874' to 10894' at 1/2 SPF or 10 holes total. RIH with gun #2 from 10828' to 10848' at 1/2 SPF or 10 holes total. RIH with gun #3 from 10774' to 10794' at 1/2 SPF or 10 holes total. Total perforations this interval: 30. RD Dresser-Atlas. RU Dowell-Schlumberger Frac. lines. Press. Annulus to 3000#. Prime Frac. lines and test to 10800#. Acidize HN-HR with 15% HCL (per following). Pump 5 bbls. FIW spacer, 4 bbls. acid, 15 bbls acid with 60 ball sealers at equal spacing, 5 bbls. acid followed by 108 bbls. 40# linear gel frac fluid. Max. THP at 9893# at 0.3 BPM. Ball out with continued injection occurred until breakdown during last 4 bbls. Surged SBBI/102188 11 DAILY REPORT OF OPERATIONS (continued) C13-23 DATE 10/23/88 10/24/88 10/25/88 SBBI/102188 DESCRIPTION three times to drop balls. Injectivity test - Pump 60 bbls. of 40# GEL at 15 BPM +/- at 9636#. Repair packing on turbine pump. Remove ball injector. Retest lines to 10900#. Repair turbine pump control connector. Continue injectivity test (per following) pump 108 bbls cross linked Gel at 20 BPM with MAX 9459#. Follow with 70 bbls cross linked 40# GEL and 100 mesh sand at 20 BPM with 9400#. Chase with 108 bbls linear 40# Gel at 20 BP, with MAX. 9700#. Evaluate injectivity test information. Plan for HN-HR Frac. Fill tanks with water and build Gel to assure 1500 bbls of Gel on hand. Prepare for Frac of HN-HR. Evaluate injectivity test, monitor well, build Gel, Prep. for Frac. Fracture stimulate HR-HN with SF240 carrying 20/40 Carbolite, using PPR and POD for ramp fracture. Pump 250 bbls SF240, 73 bbls SF240 carrying 100 MESH, chase with 591 bbls 20/40 proppant (Carbolite), flush with 22 bbls WF40; sand out occurred. Pressures: at start CSG. 3209, TBG. 920, shut in, CSG.3374, TBG. 10552, ~ 5 min. CSG. 3374, TBG. 7225, ~ 10 min. CSG. 3374, TBG. 7115, @ 15 min. CSG. 3411, TBG. 6932. Shut in well and monitor. Rig up for back flow with 2" line through choke to production group I separator. Build pit volume with 9.6#/Gal. 145 bbl saltwater. Back flow well - initial tubing pressure at 1800#, flow rate at 20 BPH. Shut in for PBU-ending tubing pressure at 95#, flow rate @ 2.3 BPH. Pick up 2 7/8" tubing, make up stands using mousehole, stand back in derrick. Pumped 10000# of 100 mesh and 84000# of 20-40 sand. Shut in well, psi built up to 1000#. Bleed well pressure off to prod. Separator. Backflow well. Shut in well, psi built up to 725#. Continue to Backflow well to Prod Separator. Shut in well, psi built up to 300#. Rigging for kill. 83 bbls recovered in 29.5 hrs. avg. 2.8 bbls/hr backflow rate. Rig up kill lines, pickup tbg. string opening circ valve with 500 psi on the annulus. Reverse circ. 77 bbls to PROD Separator; 2" line plugged off with frac sand. Switched returns to 6" gas buster line; plugged same. Switched to 4" reserve pit line and reversed out 7 drums of Frac. Sand. weight up to 9.8 PPG after clearing tubing.of sand. Check for flow, none. POH, lay down RTTS. Make up Mule Shoe and 12 DAILY REPORT OF OPERATIONS (continued) C13-23 DATE 10/26/88 10/27/88 10/28/88 11/20/88 DESCRIPTION TIH. Tagged up on sand at 10275'. (Have 937' of sand to reverse out). Reversing out frac. sand to 10458'. Reverse out sand to 11212'. Put all sand into 20 55 gal drums. Reverse Circ. hole volume. Check for flow, none. POH with mule shoe. Rig up Dresser-Atlas, run gage ring and junk basket to 10600'. O.K. POH with Dresser. Finish gage ring and junk basket run. Rig and ran Baker model "DB" PKR in hole, tied in w/CCL, set top of PKR at 9762' WLM. Otis re-entry guide at 9805' WLM. (29' difference between WLM and SLM) per SLM; top of PKR, 9791' re-entry guide at 9834'. This is per 2 7/8" tubing strap, 10/26/88. Tear out Dresser-Atlas CNG pipe rams to 2 7/8". Test to 5000# O.K. Rig/Run completion string; all measurements are SLM: EOT at 9834', XN nipple at 9824', top of PKR at 9791'. (Seal bore extension is 9.31') Otis sliding sleeve at 9746', CAMCO GLM's at*(tops)* 9672 - 8874' - 8250' - 7495' - 6557' - 5221' - 3629' - 1771', Flopetrol SSSV at 317'. Tubing located and slacked off 20" or 12,000# down on LDG collar. Down weight was 65K, up weight was 9OK. 311 jts. of 2 7/8" 6.5# N-80 8 RD EUE AB mod TBG was ran. Test TBG to 2000#. O.K. Sheared out plug in Otis wireline Re-entry guide at 2500#. Closed rams, test down on TBG hanger seals with 3000#. O.K. Rig up slickline, pulled dummy valve, ran 2 1/8" dummy gun to 10000'. O.K. Rig down slickline. Set back pressure valve. Nipple down BOPE. Nipple up tree. Test production tree at 5000 psi, install safety air valve and choke, prepare Rig to skid to C24A-23. Release rig to C24A-23 at 0800 hrs., 10-27-88. Rig accepted at 0600 hrs. 11/19/88. Move on location. Rig up Western-Atlas wireline, test lubricator to 1500 PSI. OK. RIH with silver jet bar Gun loaded 4 JSPF. Perforate from 10720' to 10734' and 10704' to 10716' POH. Flow test well to separator. RIH, per~orate from 10,674' to 10,704', POH. Flow test well to separator. RIH, perforate from 10638' to 10668', POH. Flow test well to separator. SBBI/102188 13 DAILY REPORT OF OPERATIONS (continued) C13-23 DATE _ ~ _ 11/21/88 11/22/88 11/23/88 DESCRIPTION Flow test well to separator. Run #4; perforate from 10608' to 10638'. Run #5; Perforate from 10578' to 10608'. Flow test well to separator. Run #6; perforate from 10545' to 10549' and 10530' to 105411 · Flow test well to separaor. All guns are 2 1/8" Silver Jet Bar loaded 4 JSPF. Flow test well to separator. Run #7; perforate from 10420' to 10437' and from 10409' to 10416'. Flow test well to separator. Run #8; perforate from 10379' to 10,409'. Flow test well to separator All guns are 2 1/8" Silver Jet Bar loaded 4 JSP~. Flow well to test separator. Run #9; Perforate from 10,272' to 10,278' and 10,241' to 10,268'. RD Atlas. Tear out Rig from move. All guns fired this well are Silver jet bar loaded 4 JSPF. Rig Released at 1200 hrs. 11/22/88. SBBI/102188 14 SURVEY.REPORT SHELL WESTERN EXPLORATION & 'PRODUCTION, INC. MIDDLE GROUND .SHOALWELL '13'23 KENIA, ALASKA OCTOBER 12, .1988.~ ORI61NAL Gyrodata Incorporated RO. Box 79389 Houston, Texas 77224 713/461-3146 October 12, 1988 Mr. Randy Wagner Shell Western Exploration & Production 601 W. 5th St., Suite 810 Anchorage, Alaska 99501 RE: Middle Ground Shoal Well 13-23 Kenai, Alaska Dear Mr. Wagner: Enclosed please find one (1) original and six (6) copies of the completed survey of Well 13-23. We would like to take this opportunity to thank you for using Gyrodata and we look forward to serving you in the future. Sincerely, Gary W. Uttecht Vice President, Technical Services GWU/cv Enclosure Gyrodata Services, Inc. Hr 'on, TX/Lafayette, LA/New Orleans, LA/Ventura, CA/Aberdeen, U.K./Calgary, Alberta A Gyrodat a Direct i ona 1 for SHELL WESTERN E & P, INC. MIDDLE GROUND SHOAL WELL I3-23 KENAI, ALASKA Survey Date Run: 10-0CT-88 5:30:0 ~ob Nur~ber: AK1088G110 Surveyor: AL KUDRLE Calculatior~ Method: MINIMUM CURVATURE Survey Latitude: 60deg 45rain 50sec N i Bearings Cc, rrec~ed ldeg 18r~in Osec EAST to Grid North · Proposed Well Direction: N 85deg Or~in Osec E Vertical Section Calculated fro~ Well Head Location Closure Calculated fro~ Well Head Location Horizontal Coo'r~dinates Calculated fror~ Local Horizontal Reference ~HELL WESTERN E & P, INC. tlDDLE GROUND SHOAL WELL I3-23 <ENAI, ALASKA lob Nut, bet: AKI088Gl10 A Gyrod at a Directional Survey Page MEAS I NCL DEPTH ft deg ~in .0 0 0 I00.0 0 14 200.0 0 12 300.0 0 17 400· 0 0 20 500.0 1 25 600.0 5 51 700.0 7 35 800.0 8 14 900.0 9 15 1000.0 9 59 1100.0 II I7 1800.0 15 8 1300.0 19 36 1400.0 23 6 500.0 26 33 600. 0 30 15 700.0 34 37 800.0 36 59 900.0 36 54 2000.0 36 26 2100.0 35 28 2800.0 35 17 2300.0 34 40 2400.0 34 22 2500.0 34 5 2600.0 33 43 2700.0 33 32 2800.0 33 8 2900.0 33 20 BORE HOLE BEARING deg ;~in N 0 OE S 45 55 W S 57 55 W S 15 14 W S 20 54 E NI2 OE N 818E N 450W N 3047W N56 21 W DOG-LEG VERT VERT SEVER I TY DEPTH SECT I ON deg/100' ft ft CLOSURE DISTANCE BEARING ft deg min .00 .0 .0 .0 N 0 0 E MEASURED DEPTH REF TO PLAT C RKB ELEV 105' TO MSL MULTISHOT GYRO SURVEY RUN IN 9 5/8" CASING AND 7" LINER .23 100.0 -.2 .2 S 45 55 W · 05 800.0 -.5 .6 S 49 37 W .19 300.0 -.7 1.0 S 42 56 W .80 400.0 -.7 1.4 S 86 43 W I. 70 500.0 -. 3 4.44 599.8 1.3 8.31 699.1 2.5 3.60 798.2 -. 6 3.98 897.0 - 10. 0 N 78 54 W 3.81 995.7 -24.7 S 8I 54 W 3. 75 1094.0 -42.8 S 84 49 W 3.81 1191.3 -65.5 S 85 59 W 4.58 1286.8 -95.3 S 86 ~S W 3.50 1379.9 -131·7 86 21 W 8'? 4W 87 50 W 86 56 W S87 44 W S 88 88 W S 88 47 W S89 15W S 88 58 W S 88 3W S 88 34 W S8931W S89 12W N 89 36 W N 89 53 W .4 S41 IlW 6.0 N 7 7E I7.6 N 3 0 E 30.5 N 6 I3 W 43.1 N 18 28 W 55.2 N 31 32 W 66.7 N 44 50 W 82.8 N 57 16 W 108.0 N 66 58 W I41.4 N 73 36 W $.45 1470.6 -173.6 3.71 1558.6 -821.2 4.39 1643.0 -874.7 2.43 1724.1 -333.2 .49 1804.0 -393.2 181.4 N 78 I1 W 227.7 N 81 18 W 280.4 N 83 26 W 338.3 N 85 1 W 397.9 N 86 10 W .64 1884.2 -458.8 .98 1965.2 -511.4 .32 2046.7 -569.8 · 63 2128.7 -626.4 · 61 2811.0 -682.9 457.4 N 86 55 W 515.9 N 87 25 W 573.7 N 87 47 W 631.0 N 88 4 W 687.5 N 88 21 W .41 2293.7 -739.1 .64 2376.7 -794.7 .26 2468.0 -849.9 .77 2543.5 -904.7 .25 2627.2 -959.2 743.7 N 88 36 W 799.4 N 88 46 W 854.8 N 88 53 W 909.7 N 88 58 W 964.5 N 89 1 W HORIZONTAL COORDINATES feet .00 N .00 E .14 S .14 W .37 S .44 W .70 S .65 W 1.21S .61W .28 S .25 W 5.96 N .74 E 17.57 N .92 E 30.30 N 3.30 W 40.91 N 13.67 W 47.04 N 28.87 W 47.33 N 47.06 W 44.78 N 69.67 W 42.43 N 99.34 W 39.92 N 135.66 W 37.15 N 177.56 W 34.44 N 825.03 W 32.07 N 278.59 W 89.39 N 337.02 W 26.60 N 397.05 W 84.68 N 456.73 W 83.82 N 515.41 W 82.28 N 573.89 W 81.34 N 630.61 W 19.86 N 687.86 W I8.19 N 743.48 W 17.25 N 799.85 W 16.63 N 854.62 W 16.48 N 909.57 W 16.67 N 964.37 W SHELL WESTERN E & P, INC. qlDDLE GROUND SHOAL WELL 13-23 <ENAI, ALASKA Iob Number: AK1088Gl10 Gy rod at a D i r ect i o r~a 1 Survey Page 2 MEAS INCL BORE HOLE DOG-LEG DEPTH BEAR ING SEVER ITY ft deg rain deg rain deg/100' 3000.0 33 3 3100. 0 32 43 3200.0 32 48 3300.0 32 23 3400.0 32 3 3500.0 31 55 3600.0 31 13 3700.0 31 4 3800.0 30 47 3900.0 30 27 4000.0 30 22 4100.0 29 9 4200.0 28 56 4300.0 29 7 4400.0 30 19 4500.0 32 20 4600.0 33 36 4700.0 34 37 4800.0 35 56 4900·0 37 46 5000· 0 39 7 5100.0 38 22 5200.0 37 35 5300.0 37 14 5400. 0 36 45 5500. 0 36 24 5600· 0 35 57 5700.0 35 27 5800·0 34 17 5900.0 33 59 N89 12W N 88 55 W N89 7W N 88 27 W N 88 28 W N87 29 W N 86 59 W N 86 26 W N 85 38 W N 84 43 W N 83 32 W N 82 32 W N8i 35W N 79 38 W N 78 OW N 76 20 W N 75 45 W N 75 20 W N 74 8W N72 4W N72 18W N71 59W N71 5W N 70 30 W N 69 37 W N69 5W N 68 50 W N68 6W N69 2W N 67 58 W · 47 · 37 .13 .55 · 33 .54 .75 .32 .49 .58 · 60 I. 32 .50 .97 1.44 2. 20 1·31 1.05 1· 48 2·22 1.35 .77 · 95 .50 · 72 .47 .49 .66 I. 27 .67 VERT VERT DEPTH SECTION ft ft 2710.9 -1013.7 2794.9 -1067.7 2878.9 -1121.6 2963.2 -1175.1 3047·8 -1228.1 3132.6 -1280.6 3217.8 -1332.5 3303.4 -1383.7 3389.2 -1434.4 3475.3 -I484.6 3561.5 - 1534.3 3648. 3 -1582. 9 3735.7 - 1630.2 3823. 2 -1677. 2 3910·0 -1724.8 3995.5 -1774.3 4079.4 -1825.7 4162.2 -1878.6 4243.8 -1932.8 4323.8 -1988.4 4402.1 -2045.7 4480. 1 -2103. 4 4559.0 -2159.8 4638. 4 -2215.2 4718.3 -2269.8 4798.6 -2323.5 4879.3 -2376.5 4960.5 -2428.7 5042·6 -2479.9 5125.3 -2530. i CLOSURE DI STANCE BEARING ft deg 1019.3 N 89 2 W 1073.5 N 89 2 W 1127·7 N 89 2 W 1181·5 N 89 2 W 1234.8 N 89 0 W I287.8 N 88 58 W 1340.1 N 88 54 W 1391·8 N 88 49 W 1443.1 N 88 43 W 1493.9 N 88 36 W 1544.4 N 88 27 W 1593.8 N 88 17 W 1642. I N 88 6 W 1690.2 N 87 53 W 1739.2 N 87 37 W 1790.3 N 87 19 W 1843.7 N 86 59 W 1898.7 N 86 39 W 1955.2 N 86 18 W 2013.7 N 85 55 W 2074.1 N 85 30 W 2135.0 N 85 7 W 2194.9 N 84 44 W 2253.9 N 84 22 W 2312.3 N 84 0 W 2370.0 N 83 38 W 2427.1 N 83 17 W 2483.5 N 82 56 W 2539.0 N 82 37 W 2593.4 N 82 19 W H 0 R I Z 0 N T A L COORDINATES feet 17.11N 1019.1I W 18.00 N 1073.40 W 18·93 N 1127.50 W 20.07 N 1181.35 W 21.50 N 1234.63 W 23.36 N 1287.56 W 25.89 N 1339.84 W 28.86 N 1391.47 W 32.41 N 1442.74 W 36.69 N 1493.49 W 41.87 N 1543.84 W 47.89 N 1593.11 W 54.60 N 1641.20 W 62. 52 N 1689.07 W 72.15 N 1737.68 W 83.72 N 1788.36 W 96.84 N 1841.16 W 110.84 N 1895.47 W 126.05 N 1951.18 W 143.51 N 2008.54 W 162·53 N 2067· 73 W 181.72 N 2127.29 W 201.21 N 2185.65 W 221. I9 N 2243.03 W 241.70 N 2299.59 W 262.71 N 2355.35 W 283.90 N 2410.43 W 305.31 N 2464.70 W 326.21 N 2517.91 W 346.78 N 2570. 13 W SHELL WESTERN E & P, INC. ~IDDLE GROUND SHOAL WELL 13-23 {ENAt, ALASKA ;ob Number: AK1088Gl10 A Gyrodat a D i r ect i o ~f a 1 Survey Page 3 MEAS INCL BORE HOLE DOG-LEG DEPTH BEAR ING SEVER ITY ft dec rain deg rain dec/100' 6000.0 32 59 6100.0 3I 57 6200.0 31 12 6308.0 30 16 6400.0 89 40 6508. 0 28 39 6600.0 27 3 6708.0 23 1 6800.0 20 85 6900.0 17 55 7000.0 15 58 71~-~.0 13 51 7200.0 12 24 7300.0 10 51 7400.0 10 30 7580.0 9 38 7600.0 9 5 7700.0 9 4 7800.0 9 39 7900.0 10 23 8000.0 10 47 8i00.0 12 1 8800.0 i1 59 8308.0 12 56 8400.0 13 21 8508.0 14 5 8600.0 14 40 8700.0 I4 7 8800.0 14 i3 8900.0 13 0 N 66 57 W N 66 46 W N 65 24 W N645I W N 64 22 W N 63 37 W N62 1OW N 58 49 W N 52 43 W N4641 W N423i W N 35 37 W N34 lOW N28 18 W N 16 18 W N 93I W N 211E N 1229E N I843E N 26 52 E N 32 5E N 36 44 E N40 10E N4341 E N 44 56E N 47 57 E N 50 35 E N54 14 E N5741 E N 64 24 E 1.14 1.05 1.03 .96 .65 1.07 i. 75 4.27 3.43 3.18 2.31 2. 75 1.49 I. 96 2.23 1.47 1.97 1.62 1. I7 1.60 1.04 1.54 .71 1.21 .5I 1.02 .88 I. 07 .85 1.99 VERT VERT DEPTH SECTION ft ft 5208.7 -2579.0 5293. 1 -2626. 4 5378.3 -2672.2 5464. 3 -2716.5 5550.9 -2759.6 5638.2 -2801.4 5726.6 -2841 · 0 5817.2 -2875. 8 5910. I -2904.5 6004.6 -2927. 7 6100.2 -2946.3 6196. 9 -2960. 8 6294.3 -2972.1 6392. 2 -298i. 0 6490.5 -2986.5 6589. 0 -2989. · 6687.6 -2988.7 6786.4 -2985. 3 6885. I -2979.6 6983.5 -297 I. 4 7081.8 -2961.0 7179.9 -2948.5 7277.7 -2934.2 7375.3 -2918.4 7472.7 -2901.2 7569.9 -2882.6 7666.7 -2862.4 7763.6 -2841.5 7860.5 -2820.1 7957.7 -2798.7 CLOSURE DISTANCE BEARING ft deg min 2646.8 N 82 i W 2698.6 N 81 43 W 2749.1 N 81 25 W 2798.2 N 81 7 W 2846.1 N 80 50 W 2892.8 N 80 34 W 2937.3 N 80 17 W 2977.2 N 80 1 W 3010.9 N 79 43 W 3039.4 N 79 25 W 3063.4 N 79 6 W 3083.2 N 78 48 W 3099.6 N 78 31 W 3'113.3 N 78 14 W 3123.7 N 77 57 W 3131.2 N 77 40 W 3135.7 N 77 23 W 3137.2 N 77 6 W 3136.4 N 76 48 W 3133.5 N 76 29 W 3128.5 N 76 10 W 3121.6 N 75 50 W 3113.1 N 75 29 W 3103.2 N 75 8 W 3092.1 N 74 46 W 3079.9 N 74 23 W 3066.2 N 74 0 W 3051.5 N 73 37 W 3036.0 N 73 16 W 3019.7 N 72 57 W HORIZONTAL COORDINATES feet 367.92 N 2621.09 W 389.01 N 2670.45 W 410.22 N 2718.31 W 431.72 N 2764.67 W 453.14 N 2809.80 W 474.50 N 2853.59 W 495.77 N 2895. 18 W 516.51 N 2932.02 W 537.21 N 2962.63 W 558.34 N 2987.72 W 579.03 N 3008.21 W 598.90 N 3024.48 W 617.52 N 3037.48 W 634.71 N 3047.96 W 651.75 N 3054.97 W 668.74 N 3058.91 W 684.88 N 3059.99 W 700.45 N 3057.99 W 716.08 N 3053.60 W 732.05 N 3046.83 W 748.02 N 3037.79 W 764.30 N 3026.59 W 780.58 N 3013.66 W 796.61 N 2999.24 W 812.88 N 2983.35 W 829.21 N 2966. i6 W 845.40 N 2947.34 W 860.57 N 2927.66 W 874.26 N 2907.39 W 885.68 N 2886.87 W ~HELL WESTERN E & P, INC. ~IDDLE GROUND SHOAL WELL 13-23 {ENAI, ALASKA ~ob Number: AK1088@110 A Gyrodat a Direct ional Survey Page 4 MEAS INCL BORE HOLE DEPTH BEAR ING ft deg r~in deg 9000.0 12 10 N 66 18 E 9100.0 12 59 N 70 46 E 9200.0 14 3 N 71 9 E 9300.0 13 35 N 72 48 E 9325·0 13 53 N 76 41 E 9350.0 I4 5 N 84 43 E 9400.0 14 58 S 87 21 E 9500.0 15 24 N 87 6 E 9600.0 15 38 N 87 7 E 9700.0 15 42 N 86 33 E 9800.0 16 11 N 86 24 E 9900.0 17 58 N 86 47 E I0000.0 19 16 N 87 43 E 10100.0 21 29 N 87 0 E 10200.0 24 19 N 84 35 E 10300.0 26 17 N 83 54 E 10400.0 28 43 N 81 59 E 10500.0 31 42 N 80 49 E 10600.0 36 52 N 80 3 E 10683.0 41 53 N 77 50 E DOG-LEG VERT VERT SEVER I TY DEPTH SECT I ON deg/100' ft ft CLOSURE DI STANCE BEARING ft deg .93 8055.3 -2778.2 3003.5 N 72 40 W 1.27 8152. 9 -2757. 3 2986. 5 N 72 24 W 1.08 8250.2 -2734.6 2967.8 N 72 8 W · 61 8347.3 -2711.4 2948.5 N 71 52 W TWO EXTRA STATIONS TO DEFINE LARGE DOGLEG 3. 87 8371.6 -2705.5 2943.5 N 71 48 W 7.78 8395. 8 -2699.5 4.35 8444.2 -2687. 0 I . 52 8540.8 -2661 · 0 · 24 8637. 1 -2634.3 · 16 8733.4 -2607.3 2938.2 N 71 45 W 2926.4 N 71 40 W 2901.6 N 71 30 W 2876.7 N 71 18 W 2851.7 N 71 6 W . 49 8829. 6 -2579. 8 1.79 8925.1 -2550.5 i. 34 9019. 9 -2518. 6 2.23 9113.6 -2483.8 2.98 9205. 8 -2444.9 2826.3 N 70 54 W 2799.2 N 70 40 W 2769.7 N 70 25 W 2737.5 N 70 8 W 2702.0 N 69 48 W I . 99 9296.2 -2402.2 2.58 9384.9 -2356. 0 3.04 9471.3 -2305.8 5. 18 9553. 9 -2249. 7 6·29 9618.0 -2197·4 2663.7 N 69 24 W 2622.9 N 68 56 W 2579.3 N 68 23 W 2531.3 N 67 43 W 2487.5 N 67 3 W HORIZONTAL COORDINATES feet 894.78 N 2867·08 W 902·71N 2846.83 W 910.33 N 2824·73 W 917.73 N 2802·02 W 919.29 N 2796.29 W 920.26 N 2790.35 920·52 N 2777.84 920.60 N 2751.69 921.95 N 2724.98 923.44 N 2698·02 925·13 N 2670·61W 926.87 N 2641.31 W 928.39 N 2609.42 W 930.00 N 2574.64 W 932.91 N 2535.85 W 937.20 N 2493.33 W 942· 91 N 2447.51 W 950.45 N 2397.78 W 959.82 N 2342.26 W 969.97 N 2290.61 W Final Station Closure: 2487·5 feet North 67 deg 2 r~in 58 sec West I~0 U $'1"0 N INSTRIJ ~2,1- NT ............. AUSI IN, TLXAb CH^RT NO, 10!515-L : . i I i J'" 5HELL iNESTERN E & P, INC. i ' HI.I].I]LE 6ROUN[I 5HOFIL NELL J3-23 I' I ..................... iKENFI [-;;--RLRSKR ..... RK'J 888~6] ] L . ~ ................... ~ . SHELL NEST;ERN E & P,'INE. , ~ - ! 'J' i' . -. l HI~DLE ~RDUNB SHill:IL NELLi .1.t-23 I i J ..__L __ ,_~,__,-~ : :;: . :. :. -'K'ENR [-;-"Fli'nc~'t:l ............................ P .............................. ~ .............................. ~ --~ .... !~1~I~--1 .... -' .... I-- _ j --_ / ': RK,']~88~],1~ . !: ' · . i ' ',' :, ' '::..: :..:' . . :'. ;-- :_t: ' ~ ! --~- ~ :~.~-~-~-~ ...... :, ............................ L~ ....._"_~_._~..L_..' ........ : ....... ~._~.___i___"..~ ........ i ~i~_Lxl.__~_.~,~_ ~'_' ...... t i -, ': · T ' i ...... ~i .... · ' ~ ', : ~ - ! ·' ' i! · ' I ............. : i .... ' i '.' .' '! i ' I i : 'i I ' "' il: ' ::i::': ':":. ....................................................................................... ' ........ ~ ...................... : ................................. ~ ................... ', ........... ~ ..................... '; ........ I- ..... -: ........................... E . i t L__ ............. I .................................................... i . . ....... ~ .... ~ .-~ ...... ~ ............ ,,. I I. t - - I "'i ....... ? .... ~ ' "':':-' . -~ .............. ...... . ....... _ ...... [ I ! :_.;:I ..... {. -! . i :-';'._{'::-' ! -.t-- October 12, 1988 Mr. Ed Unger Shell Western E and P Inc. 601 W. 5th Ave. Anchorage, Alaska 99501 Re: Our Level Rotor Gyro Survey Job No. AK-LB-80115 Well: C13-23 Field: Middle Ground Shoal Operator: Harger Mr. Unger: Please find enclosed the "Original" and one (1) copy of our Level Rotor Gyro Survey on the above well. Thank you for giving us this opportunity to be of service. Sincerely, NL SPERRY-SUN, INC. Ken Broussard District Manager Enclosures NL Sperry.Sun/NL Industries, Inc. P.O. Box 231649, Anchorage, Alaska 99523-1649 Tel. (907)522-1737 SHELL WESTERN E & F', C: 13-23 MIDDLE GROLIND SHOAL ALASKA I NC:, .:,FERRY-,.LN WELL SURVEYINO 6:OMPANY ANC:HORAGE ALASKA COMPLITATION DATE F~CTOBER 12, 1'- VERTICAL SECTION CALCULATED ALONG CLL'L"_-';URE DATE OF SURVEY OCTOBER LEVEL ROTOR GYRO JOB NUMBER AK-LB-80115 KELLY BLISHiNG ELEV. = OPERATOR-HARGER PAOE 1 1, 1 ?88 1C) 5.00 FT. TRUE SLIB-SEA C:OURSE C:OLIRSE DOG-LEG ""~ASI_IRE D VERT I CAL VERT I F:AL I NCL I NAT I ON D I REC:T I ON SEVER I TY ,--!F TH DEF'TH DEF'TH DEG M I N DEGREE:--.; DEG / 100 TOTAL REC:TANGULAR C:FH_-fRD I NATES NORTH/SOUTH EA'._--;T / WE:.--.;T VERT I C:AL S E C: T I 0 N 10000 .901 '?..90 8'? 14. ?0 1'? 16 N 87.72 E 0.00 .928.40 N 260.9.40 W 10100 ?113,.96 ~008,76 20 '25 N 87..92 E 1. 15 ~27.6¢~ N 2575·48 W 10200 92~6. ..... '~) '~101 , .90 22 s('~ .... N AA. F~. E 2, 52 9:-41. _ ,67 N z'-'s~"~._.;,._,. 69. W 10300 ?2?8. i'P ~17:3. I? 25 2:0 N 83.44 E 2.71 ?:}5.46 N 24?8.07 W 10400. .9:387 .6/-_ ?282 ,66 27 4(')_ N ~_ ._. 22 E 2 . ._'~4 '?4A../-.4_ N ~'~'~._,._,. 77 W 10500 ?475 3.9 ?370 '~9 2~ 40 N 80 61 E ~.~::, .947.42 N 2406:30 W 10600 ~SAA 13 .9455, 1'-4 :34 '-'% ..... :,._, N ....... z._ N 79, 41 E 4 7? ~%/-, ~= ~._.._,.'~'-~%~ 07 W C'1'(~700 9639.57 ~5:34.57 40 20 Va?,~ N 78.88 E 5.93 968. 10 N 2294.4e W '10800 9712. AA ..... 'DAA7, 68 45 40'/:r.G] N 75.~8_ E 5.78 ¢q'~. ,_ ~., 25 N 2228.03 W 10 s?('~ 0 o. 778, 81 'P673,81 51 :::_ 0 ~ ~/,¢ ~ 0 N 77, 1 o.. E 5.95 1000, 85 N 21 ._~._%, 17 W 11000 78:37,40 77:32,40 56 455~,n~ N 7.9.91 E 5.70 tot6.85 N 2075.78 W 111F)0 9891.55 97o6.55 57 405~.¢ N 81.75 E 1.79 1030.23 N 1992.80 W 1116~ ?P28.37 982~.:}7 57 50~.~5 N 83.53 E 2.21 10:37.70 N 1.934.73 W 2738.3/.:, 270'~. 07 2677, 2642::, ;'? 60/.:,. 2' 568 2526.70 2,47 ?. · %, -'2., ,. 4.,.._.. 20 2372.30 2:3:0 O. -o0 224 ,.:,. 10 '? 1 c/% A"~' HORIZONTAL DISPLAC:EMENT = 21F~5./_-.3 FEET AT NORTH 61 DEG. 47 MIN. WEST AT MD = 11167 THE CALCULATION F'ROCE[,UREL--; ARE BAS, ED C,N THE USE OF THREE DIMENSIONAL RADIU'..-]; OF CLIRVATLIRE METHOD. SHELL WESTERN E & F', INC. C13-23 MIDDLE GROUND SHOAL ALASKA SF'ERRY-SUN WELL SURVEYING COMPANY ANCHORAGE ALASKA COMPUTATION DATE OCTOBER 12, 1788 PAGE DATE OF SURVEY OCTOBER 11, 1S~88 dOB NLIMBER AK-LB-S0115 KELLY BUSHING ELEV. = 105.00 FT. OPERATOR-HARGER INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SLIB-SEA TOTAL J~SLIRED VERT I CAL VERT I C:AL RECTANGLILAR C:OORD I NATES; MD-TVD VERT I CAL DEF'TH DEPTH DEPTH NORTH / SOLITH EAST/WEST D I FFERENCE CORRECT I ON 0000 9017.?0 8714.90 728.40 N 2607.40 W ?80. 10 1000 ~837.40 ~732.40 1016.85 N 2075.78 W 1162.60 182.50 11~'~ oo?o -)7 '~:~ '~c: 37 lr~7 7('~ N 1734 '~ W 124r~ 62 78 r~2 THE CALC:LILATION F'ROC:EDLIRES ARE BASED ON THE LISE OF THREE DIMENSIONAL RADIUS OF C:LIRVATLIRE METHOD. WELL LOG INVENTORY WELLNAME : ~~5 PAGE LOG LOG COUNT DATE REC RUN# CDM (mudlog) DIL/SFL (dual induction log) CNFD (compensated neutron density) (compensated neutron formation/ litho-density) CFD (compensated formation density) BHC/SL (borehole compensated sonic) LSS (long spaced sonic) SSS (short spaced sonic) CYB (eyberlook) GCT (groscopic survey) DIPMETER SAMPLES: Required yes/n~ Date Received: Comments: L--~) ~-'~ C'6 ~ --= ORGE'S COURIER SERVICE 344-3323 59R 4 COMPANY LOCATION A3-rENTION WELL~ SERVICES : NO. OF BOXES' JOB NO. ' ADD'L TAPES ' WELL NAME :I~ SERVICES NO. OF BOXES JOB NO. ADD'L TAPES WELL NAME SERVICES ' FROM · ADDRESs CITY SHIPPER TO cITY ?;-~ (~ ¢' ' A~ENTION ~} ~'/¢ ~ PHONE INSTRU~IONS STATE ZIP . DATE,.J ///,~~' TIME ZIP qG CENTER NTER SAME DAY ~ 24 HOUR [] P/U BY 3PM CASE NO. COURT DOCUMENTS [] ONE HOUR ONE HOUR $ SAME DAY $ 24 HOUR $ OTHER $ TOTAL $ X OF BOXES' NO. OF BOXES: ~ JOB NO. ' ,i~A~[ .t. ' 0~miSS't0~_ _ ..,_ADD'L TAPES ADD'L TAPES '~k,~S%~ -" A~C~~~~~ . - SCHLUMBERGER COURIER:_ ELIVERED: ~ Telecopy No. (907) 276-7542 February 8, 1989 M L Woodson, Manager Division Operations Shell Western E&P Inc 601 West 5th Ave, Suite 810 Anchorage, AK 99501 Re: Revised API numbers Dear Mr Woodson: The API numbers for the following Middle Ground Shoal-F~.eld wells have been changed. Please make the necessary changes to y6ur records. C-13-23 Approved as: 733-20402-00 Cha~ed to: 733-20403-00 C-43-14 733-20403-00 733-20404-00 if you have questions, please call me at 279-1433. j o/g. JNM, ] RETAIN THIS SECTION FOR YOUR RECORDS RE MGS C13-23 & MGS C24A-23 ACBL/V/S's 1 PRINTS 0 NEG ~~//1~ N TS NEG ~ PRINTS NEG ~_~l,,~,.~_rJ~ o PRINTS NEG . . PRINTS NEG Gas (~011S, ~Om~itPRi NTS NEG ~.chorage · PRINTS N EG ABOVE RECEIVED FROM: DRESSER ATLAS JOHN BOYLE ATTENTION SIGNED DATE SEPIA SEPIA SEPIA SEPIA SEPIA SEPIA SEPIA SEPIA 19__ Shell Western E&P, P.O. Box 527 Houston, TX 77001 Attention: Log Fi 1 es, WCK 4147 SCHLUMBERGER WELL SERVICES DIVISION OF SCHLUMBE:I~GEI~ T£CHNOLO~-~Y COI~PORATION HOUSTON. TEXAS 77251-2175 PLEAIE REPt. Y TO N o v em b e r 7, 1 9 8 8 SCHLUMBERGER WELL SERVICES 500 W. International Airport Anchorage, Alaska 99518 ATTN: Print Room Inc. Gentlemen' 2" & 5" DIL (RUN 1) 2" 5" , Enclosed ore 1 B L prints of the & PHASOR DIL LSS;LDT/CNL(RAW & 0)(RUN 2) on: Compony~tern E&P, Inc. Well /r C13-23 ) Field L Middl_~e ~ound Shoal County Kenai Store Alaska A~prints are being sent to: 1 BL__prints prints Shell WeStern E&P, Inc. 601 W. Fifth Ave., Suite 810 Anchoraqe, AK 99501 ATTN- Hank Van Schelt 3' BL prints Sh~ll Western E&P, Inc.. P.O. Box 527 Houston, TX 77001 ATTN: C.C. Williams WCK 1134 prints Rd. 1 BL nrints Shell' Western E&P, Inc. Platform "A" or "C" C/O Shell Kenai Office 130 Trading Bay Ave., Suite 130 Kenai, AK 99611 1 RFolded Sepia State' Of Alaska AK Oil & Gas Conservation ~mmi 3001 Porcupine Dr. Anchorage~ AK 99501 "~A~TTN: John Boyle ssion The film is returned to Shel 1 (Houston-Log Files) We appreciate the privilege of serving you. ~prints prints ~ec~Wed Date- Very truly yours, SCHLUMBERGER WELL SERVICES Marc Gunther C)I ITII ICl' M ANAOilll ~D ' ' D , BOP, ACCUMULATOR & CHOKE MANIFOLD TEST REPORT --'RECEIVED': , SEP 1 4 1988 Alaska Oil & Gas Cons. Commission Anchorage ,, ~;TATION vet ..:. PTell(u~t-, . , ,t ' : ~l,' i1 ' ~072790352~ 9072767542;# 3 .RECEIVED SEP l ~ ]988 Alask~ Oil & Gas C~ns. Commission Anchorage toc.,~.~ sec.~~J~ ~ set ~, a~~ .-.f~, ......... ~- ,~~~t~~~ ~~ ~u~ inc~. =1o~, pt~., 200 Kill Line Valve~ ~/.~~. ~ fLan~a.~ ~ ........ ~ Check Va!v~. ~. ~Ju, st~ble Chokes ~.~ Shell Western E&P Inc. 601 West Fifth Avenue · Suite 810 Anchorage, Alaska 99501 August 24, 1988 Mr. Blair Wondzell Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Wondzell: SUBJECT: TRANSMITTAL OF SPIDER DIAGRAMS FOR MGS C13-23 Transmitted herewith are spider diagrams for Middle Ground Shoal C13-23. If there are any other questions, please give me a call at (907) 263-9613. Very truly yours, S. B. Brown Environmental Technician ljm Transmittal: Spider Diagrams for MGS C13-23 SBBH/aogcc. 082488 August 24, 1988 Telecopy: (907) 276-7542 Mr. M. L. Woodson Division Operations Manager Shell Western E&P Inc. 601 W. Fifth Avenue, Suite 810 Anchorage, Alaska 99501-2257 Re: Hidd!e Gro~d Shoal C13-23 Shell Western E&P Inc. Permit No. 88-99 Sur. Loc. 618.65'FSL, 1549.76'FEL, Sec. 23, TSN, R13W, SM. Btmhole Loc. 1480'FSL, 3236'FEL, Sec. 23, TSN, R13W, SM. Dear Mr. Woodson: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not inde~uify you from the probable need to obtain additional permits required by law from other governmental agencies prior to commencing operations at the well site. To. aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention Equipment so that a representative of the Commission may be present to witness testing'of the equipment before the surface casing shoe is drilled. Where a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. BY ORDER OF THE COMMISSION dlf Enclosure Department of Fish & Game, Habitat Section w/o encl. Department of Envlrom~nental Conservation w/o encl. Mr. 'Bill H. Lamoreaux Shell Western E&P Inc. 601 West Fifth Avenue · Suite 810 Anchorage, Alaska 99501 August 16, 1988 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Gentlemen: SUBJECT: SUBMISSION OF AN APPLICATION FOR PERMIT TO DRILL MIDDLE GROUND SHOAL C13-23 Enclosed, in triplicate, is the Application for Permit to Drill the upcoming Middle Ground Shoal well C13-23. The surface location is Platform C, Leg 2, Conductor 16. Drilling operations are expected to commence August 28, 1988, and continue for two months. In the unlikely event that H2S is encountered, we intend to comply with the 20 AAC 25.065 and follow the "Recommended Practices for Conducting Oil and Gas Production Operations Involving Hydrogen Sulfide". The proposed well path is within "close" proximity of existing wells (C32-23 and C22-23). In order to prevent possible collisions we have: 1) Surveyed C32-23 and C22-23 with a north seeking gyro; 2) calculated collision cones for existing wells within close proximity of the proposed well (if the proposed well enters the collision cone, the existing well will be shut in and bled down); and 3) contracted a directional driller to be on-site. The current well plan calls for a TVD of 10,027', but SWEPI would like to maintain the flexibility to drill to a maximum prognosed TVD of 10,500'. This well will be the third well in the qovernmental quarter section. SWEPI will therefore need an exception t~ Conservation Order #44 Rule l(b). The bottom hole location of this well is in the steeply dipping, West Flank part of the field which requires closer areal well spacing than 80 acres to properly drain. If you have any questions concerning this application, please call Ms. Susan Brown at (907)263-9613. Division Operations Manager Alaska Division MLW/SBB/ljm Enclosures aogcc. 081788 STATE OF ALASKA ALASKAOII. ND GAS CONSERVATION COl, iSSlON PERMIT TO DRILL 2O AAC 25.0O5 ,,, la. Type of work Drill Re-Entry [] DeepenElI Service [] Developement Gas [] Single Zone [] Multiple Zone El 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool Shell Western E&P Inc. 105'KB feet '3. Address 6. Property Designation Middle Ground Shoal 601 West Fifth Ave., Suite 810, Anchorage, AK 99501 18756 "G" Pool .... 4' Location' of well at surface Platform "C", Leg 2, Con- 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) ductor 16.~/z¢ ~'D /¢~ o.~ ¢7, 7/~//"-/-/¢-T'_/A¢(-:-¢2'-5 Middle Ground Shoal T'bA/~..,p/~..c~-J" '" "~ 8. Well number Number 11C136503 At top of productive interval 1407'FSL and 4065' FEL Sec.23, T8N, R13W '~ C13-23 Statewide INA-Shell 0084 At total depth o~/~ 9. Approximate spud date Amount ~¢~ $100,000 1480' FSL and 3236' FEL Sec. 23, T8N, R13W ~ August 28, 1988 ss00,000 12. Distance to nearest 13. Distance to nearest- Cwell 14. Numberer acres in property 15. Proposed depth~Mea,dZVD~ property line Section 27 ~ 1865' feet C24A-23 ¢ 1150' feet 3746 11,676'MD/10027'TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth 375 feet Maximum hole angle 50 0 Maximum surlace 2116 pslg Al Iolal depth (TVD) 5725 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 17-1/2" 13-3/8" 54.5 K-55 . BTC 2376' 0 0 2376' 2253' 962sx "G" + additives 12-1/4" 9-5/8" 47&43.5 L-80 LTC 8632' 0 0 8632' 7600" 540sx "G" + additives 8-1/2" 7" 26 L-80 LTC 1909' 8332' 7301' 10241' 9039' 1090sx "G" + additives 32 P-110 LTC 1349' 0241' 9039' 11676' 10027' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor Surface Intermediate Production Liner Perforation depth: measured true vertical 20. Attachments Filing fee Drilling fluid progra~ Timevs depth plot 21. I hereby certify~t the foregoing is true and correct to the best of my knowledge Signed ~~~ Title Division 0perations Manager Date~,/~,~ Commission Use Only Permit Number ~ APl number ~ Approval date See cover letter ~-~I 50--~Z~- ~o~O ~[ 08/24/88 for other requirements Condi'tions of approval Samples required D Yes ~No Mud log required [] Yes ~No Hydrogen sulfide measures ~ Yes ~ No Directional survey required ~Yes D No Requiredworking~urefo%B~ ~2~3M; ~5M; ~ 10M; ~ 15M Other: ' by order of Approved by Commissioner the commission Date DRILLING PROGRAM MIDDLE GROUND SHOAL C13-23 1. Rig up. 2. Drill out 24" casing shoe with 17-1/2" bit. Continue drilling to 375'. 3. Kick off at 375' and directionally drill to 2376' MD using 17-1/2" bit. 4. Run and cement 13-3/8", 54.5#, K-55, BTC casing. 5. Nipple up BOP stack. Test all connections, valves, and rams to 3000 psi. Test annular preventer to 2500 psi. Test all kelly, stand pipe, and emergency valves to 3000 psi. Test casing to 1500 psi. All tests performed in accordance with AOGCC regulations. 6. Drill out 10' and perform leak off test. 7. Directionally drill 12-1/4" hole to 9-5/8" casing point. Run wireline logs. 8. Run and cement 9-5/8", 43.5 and 47#, L-80, LTC casing. 9. Nipple up BOP stack. Test all connections, valves, rams, kelly, standpipe and emergency valves to 5000 psi. Test annular preventer to 3500 psi. Test casing to 3000 psi. All tests performed in accordance with AOGCC regulations. 10. Drill out 10' and perform leak off test. 11. Directionally drill 8-1/2" hole to TD. Run wireline logs and casing caliper log. 12. Run and cement 7", 26#, L-80 and 32#, P-110, LTC liner. 13. Proceed with cased hole completion prognosis. SBBG/OSO288a RECOMMENDED MUD PROGRAM C13-23 17-1/2" HOLE Interval: 0 - 2,376' Mud Type: Spud Mud (water and gel). Generic mud #2 Recommended * Weight = 8.5 to 9.0 ppg Properties: * Funnel Viscosity = 40 to 50 sec/qt · Plastic Viscosity = 5 to 10 cp · Yield Point = 10 to 20 lb/lO0 sq ft · Fluid Loss = no control · pH : 9.0 to 9.5 Page 2 Interval: Mud Type: Recommended Properties: 12-1/4" HOLE 2,376' to 8,632' Water and gel. Disperse only if required. Generic mud #2. * Weight = 8.9 to 9.5 ppg (maintain minimum MW of 8.9 ppg in case of pressure from C 41-23 casing leak) * Funnel Viscosity : 36 to 42 sec/qt * Plastic Viscosity : 5 to 12 cp * Yield Point = 10 to 15 lb/lO0 sq ft *API Fluid Loss = 20 cc * pH = 8.5 to 9.5 * MBT = 15 to 25 Interval: Mud Type: Recommended Properti es: 8-1/2" HOLE 8,632' to 11,676' Saltwater dispersed lignosulfonate mud (1% NaC1). Generic mud #2. * Weight: 9.3 to 9.8 ppg, or as required to combat waterfl ood pressure * Salinity : 1% NaC1 * Funnel Viscosity : 40 to 45 sec/qt * Plastic Viscosity: 15-20 cp * Yield Point: 10-20 lb/lO0 sq ft *API Fluid Loss: 10 cc; 5 cc by HC * HTHP FL at 150°: less than 20 cc; 10 cc by HC * pH: 9.5 to 10.5 * MBT: 15-25 SBBG/O50288a PLATFORM 'C' SOLIDS CONTROL OPERATING MODE ~ORILLIN(3 'UNWEI'~HTEO" MUD D'IRILLINQ WEIGHTED MUD TRIPPING BUILD SLUG GATES CLOSEOl D, E, O D,E, O E, F, C, G C, D, F MUD FLOW ROUTING 1 -2-3-4-6 1 -2-3-4-6 4-5-2-3 1-2 -3-4 SOLIDS ,EOUIp,' ,IN.USE SS, 4' SS SS, 4' ,, COMME,NT,.S , . MAY WANT TO OPERATE e' 4' TURNED OFF w/WEIGHTED MUD DERRICK FLO-LINE I.... TRW '/ BRANOT I--- ~ANO · ,I, 0 T'k'~ / IT ".~ ,, I SLUG P '.: i? ~....,, c3_ ~ I Legend ~ BOTTOM EQUALIZATION ~ TOP EQUALIZATION ~ AGITATOR CASING AND CEMENTING PROGRAM C13-23 Page 4 1. Run 13-3/8", 54.5#, K-55, BTC from 2,376' to surface. Casing design criteria are attached. 2. Cement to surface using 20% excess on gaged hole volume from TD to conductor shoe. Lead with 762 sx Class "G" + 10% gel + 2% CaC12 + defoamer and friction reducer as required (12.8 ppg, 10.8 gal/sk, 1.94 cf/sk) followed by 200 SX Class "G" + 2% CaC12 + defoamer and friction reducer as required (15.8 ppg, 5.0 gal/sk, 1.15 cf/sk). Perform top job within shoe of conductor. 3. Run 9-5/8", 43.5 and 47#, L-80, LTC from TD to surface. See attached casing design criteria. 4. Cement to 7,632' MD (1000 ft above shoe) using 20% excess on caliper (preferably 4 arm caliper). Lead with an estimated 340 sx (based on a 15" hole) Class "G" + 4% gel + additives for rheologies (14.2 ppg, 7.6 gal/sk, 1.52 cf/sk, 2,000+ psi ultimate compressive strength) followed by 200 sx. Class "G" + additives for rheologies (15.8 ppg, 5.0 gal/sk, 1.15 cf/sk). 5. Run 7", 26 and 32#, L-80 and P-110, LTC from 11,676' to 8,332'. See attached casing design criteria. 6. Cement with Class "G" + 1% NaC1 + retarder + defoamer + fluid loss agent for WL less than 100 cc @ 150°F as required (15.6 ppg, 5.2 gal/sk, 1.18 cf/sk). Total thickening time between 3 and 4-1/2 hours brought up to temperature in 95 minutes. An estimated 1090 sx of cement will be required (based on an 10" hole and 300' above liner top). SBBG/O50288a Page '5 C13-23 CASING DESIGN Casing Design Criteria Frac Gradient Pressure Gradient Max Collapse Pressure Max Burst Pressure 13-3/8" .57 .47 1052 psi (Full evacuation) 1183 psi (1/3 BHP @ 9-5/8" csg pt) 9-5/8" .73 .47 3550 psi (Full evacuation) 3600 psi (injection pressure) 7" (Liner) .73 .62 10000 psi (pressure from frac jobs) 3600 ps i (injection pressure) ACTUAL DESIGN CONDITION Size Depth 13-3/8" 9-5/8" 1, 0-2376' MD 0-2253' TVD 0-4552' MD 0-4000' TVD 4552-8632' MD 4000-7600' TVD 8332-10241' MD 7301-9039' TVD 10241-11676' MD 9039-10027' TVD Weight 54.5# 43.5# 47# 26# 32# Grade/ Tension # Collapse Burst Couplin9 Wt in Mud PSI PSI K-55 BTC L-80 LTC L-80 LTC L-80 LTC P-110 LTC Casing Rating/Design Factors Tension(m) Col lapse Burst 106,000 1052 1183 853/8.04 1177/1.12 2615/2.21 294,000 1869 3600 825/2.81 3696/1.98 6393/1 145,000 3550 3600 905/6.24 4821/1.36 6708/1.86 66,000 4691 3600 519/7.86 5303/1.13 6506/1.81 27,000 10000 3600 897/33.2 10437/1.04 12204/3.39 SBBG/O50288a ATTACHMENT Page 6 The maximum pressure gradient is expected to be .571 psi/ft. Maximum BHP is expected to be .571 x 10,027 = 5725 psi. The shallowest depth at which abnormal waterflood pressures could be encountered is 8800 TVD. Maximum surface pressure is expected to be 2,116 psi, assuming a full column of .360 psi/ft oil. The well will be drilled in compliance with the Alaska Oil & Gas Conservation Commission's regulations issued April 2, 1986. As noted in the drawing of the diverter, both 10" mechanical valves will be kept in an open position until the preventer is closed. The mechanical valves will be wired open and tagged with instructions concerning proper procedures for closing a valve in the event that the preventer is closed. SBBG/O50288a SWEPI INIEHESI' titi.~/'% ALASKA DIVISION DRILLING PROGNOSIS 8/16188 WELL: C 13-23 LOCATION' PLATFORM "C", LEG 2, CONDUCTOR 16 OBJECTIVE' HEMLOCK EVALUATION GEOLOGY AFE NO' FIELD: MGS EST, ELEVATION' 105' (mean Iow Iow tide' 73') DRILLING CORES UJ 0 0 z WELL CASING ELEC. MUD SIGNIFICANT DEPTH AND SURVEYS LOGGER FORMATIONS TVD MD CEMENT t--- rr ILl O (.3 0 24' Conductor 369' 13-3/8' Surface 2253' Casing FG 9-5/8" Pro{eclive 7600 Casing GN 8800' HC 9255 HZ 9905' 7' Prod. Liner (TD) 10027' 369'~ 2376'~ 8632' 9937' 10541' 11496' 11676' HOLE DEV. HOLE AND DIR. SIZE CONTROL 17-1 ~2" 12-1/4" 8-1/2" I C c e~_ ~=E MUD PROGRAM ~ 4000' . . . ~. n.- 5000- I MAGNETIC DECLINATION ,~ 3.7°(23°,42') J ' : ' ' ' C 1 3-2 3'. ! ! ..... , GRID CORRECTION= 1.3~[1,:°? ,),- · ,! ' · SCALE" ' -1000' · NET MAGNETIC SURVEY C0RREOTION=25.0~.(25°O0')i , J ,, UPPER VERTICAL SECTIO ,,,, J i ,~ J ;. J, : ~. 'VERTICAL SECTION iAZIMUTH=281.7'~,IJ ~ : J ' ' J TARGET ,. t' ......... ~ .LOWER VERTICAL SECTION ~1.1, I .;;Ii ~1. 1 ,I ,,· . . : 700 ;i;I CHANGE TO LOWER VERTICAL: ' ' ' ; iJ i ii;I SECTION PLAT -AT;?159"IVO' BO0 ' ' ' I !. . 1;'...: .. .-i-0..:' ~ 1000 '' ; '.3000. ::!: :i :!' ; VERTfl AL SECTION (FEE3] ; ! · ~ VERTICAL SECTION AZIMUTH=~85.0o ... ;J'l .......... 1'; .... / ': i,' . ~ ~ - : ; , · ; - ~ · ~ ....... ; · i---700rl · - - ~1, t~ ;,~:.1. · i: ~: · It.. '.KOP 7159 'I'VD--J: .... :.. i . . : . i . . : . . i . ~ :~ . . · / ~ '; _; I .... .' ..... '.. I ; ; ; ...... , j ......... :.. ;, ,. : :. ~i!;.:,..l .... I. :. ~',. ,~' , . i , , t, ,. !. DR°P:::i:t'::;:i:i; .... ::; /i. " ' ;./: :' , t : :, ', : l: : 'TARGET ,111 ~(:: :'i : '9000- '~ J ! t . i ORIENTEDNgOW ~ : . . ; ' . '-- ' , : 02,55. IVD 10.541'~.MD~ : ': . -. i - I'- J;' :: t' :' i : '/' ' ~-- '' t ', · I . ~ · I . ~ ..... : .... LIJ J , '',' i: ' Y' ~00'x,~oo' .... -T .......... ,r ORiEN~ED N2<~/V ....... 10000 ~ · - , . ; : , . ORE ED i i ' ' ' : '' "rD: gl~0S' 'J'VD 11496' t · 10027 ,T, VD, ......... : - - l'' 1167{i MD;, !. :, ..... ! . ::::... ', , . '.. j . . ; : . . . i ........ : i':''Io'oo !:':'i'":':'I"' "" .... 4'i-, 11000 .... ! ' !2000' :. ; : ; ; :1000 0 '' MGS (~13-z~1 Page 24 HOLE 2000' PSI ST TOP OF KELLY BIT)SHIN~ III II 'mini I I I - .... BOTTOM OF ROTARY BEAM DRILL NIPPLE FLOW LINE ,/' ANNULAR l. PREVENTER _ ! v~ 2000PStF ~ f//'---20' 2000 PSI'FLANGE '-~ C~/ /--TO BE CONNECTED SO THAT VALVE IS ~ ~' / OPEN WHEN THE ANNULAR PREVENTER L ~ / IS CLOSED. , BOTH 10' MECHANICAL VALVES WILL BE IN AN OPEN POSITION. UPON CLOSING THE ANNULAR PREVENTER THE PROPER DIVERTER LINE IS SELECTED. I II II MAIN DECK 2000 PSI RISER II I III II I II 9/10/87 N.T.S. TOP- ,*,ELL Y I~tJSHING -- -- ~.4o,| Tot Dr Dr, FIl~l(::k, FLOOR "- BOIIOM OF ROT&R¥ BEAM D~,LL NIPPLE FLOW LINE .~ FILL UP LIN . · !: ~---J BLIND RAM 5000 PSI ~~ ~ ^M 50 13-8/8' 6000 ~'- :'~? ~ // ,/ ,~ ~_~_~ ~ ~oo~ ~r .... ~ ¢ ~ .,' ," / / .," ,~ ~ ~ ~ MA~N DE UK I ; ~000 ~ ~ PSI ~ RISER [ 13-5/8' 5000 PSI FLANGE ~ HE~D 9/10/87 1 N.T.S. NOTE: DIMENSIONS INCLUDE 1/2' GAP BETWEEN FLANGES 8-"~"~' HOLE 5000 PSI S T,~-CK Page 26 TOPL,, KELLY BUSHING , -- , ' ' 14o'1 '" '~'9 ~)r ,c ..... ' ...... L_ · P DERRI K FLOOR I III I I I i i I I I II II I ~ I I I II BOTTOM OF ROTARY BEAM DRILL , ~ NIPPLE FLOW LINE FILL UP LINE~ t~ ANNULAR ;,-- ~ PREVENTER ~ ~_.~.3-5/8" 5000 PSI FLANGE . BLIND RAM 5000 PSI ~ ~ PIPE RAM 5000 PSI ] ~""~' 13-5/8' 5000 " -~/ / / / / x ..... ~ T?P.gF .SUB. BASE_ _ ,-//////// , - ., MAIN DECK : ~ 5000 ~; PS~ ~ RISER : ~ ' ~ r ' 13-5/8' 5000 PSI FLANGE J I1' 5000 PSI FLANGE ed SPOOL _ I! WELLHEAD ROOM FLOOR I I IIII 9110/87 13-3/8' SOW X 13-5/8' 3000 PSI HOUSING N.T.S. NOTE: DIMENSIONS INCLUDE 112' GAP BETWEEN FLANGES i i iiii II I STACK tqEQqJItlIEMENT~ i i i £ i ii ii Miff. Miff. I~ ~" ii i i i i i i )~ilt~ Ni~e " _ ~~~,., ........ / I I I ii i iiii I i i i i i i i Gm Vml~ 2 1 M" : ii i i ill i i i i Go~ Volw 2. ItI~" -~qmg,~5~I ....... )11 i iii i VM~ G,~ 1.1~I~" Kilt li~ 1o ~il ~ ~P ~ll~d 2" ~ i i ii i i i 2" X 2" X 2" cfM, ii i i t OPTIONAL ~ o,, bo,'"~,c~o, ,, ' Gill volvo i~ ii ii i i i ii i i i i i i m ii I I i i .., .. DRAWING & CHECK LEST 104A - SHELL CLAS~ SM SURFACE INSTALLATIONS NORMAL AIR/GAS' CONI:IGURATION A RAM RAM SHE LL MINIMLIM HYDRAULIC OP£RATING UNIT SP[¢IFICATIONS ~ile clmi~ p~ulo, prevenlelr l~d o~nin9 ch~e li~ vllve. ~e ~l~ 4.31. i, ~1 ~trols bll ~ deafly ~ed 1o ~, u~il ~raled. llind ~m ~ to ha~ easily 1o ~-~ ~ulator I~ d~ B~ di~ly. ~orm, p v~? ~;~I~ to ~ ~n ~ul~m b ~ off from ,i i i PASt Z't~ p P tIIISCELLANE(XJS iOtJIPI~EI~ SPECIFICATICMqd$ AAID INSTALLATI01k III~RLICTIOI~ ~O~I~NT All 11~ E~: 4S HOU PROD ENGR ~., ~7 ~i WELL LOCATION PLAT MIDDLE GROUND COOK INLET SHO AL FIELD ALASKA WELL: Ct;3-2:3 LEASE NO.: ADLI8756 iL___ ~2~0 PT, '" --- 23 ! ~t~-~1 Il:it,., ...... """ i I l:41"1:1 PROPOSED LOCATION AT TOP OF OBJECTIVE: t407 FT. FROM S LINE AND 4065 FT. FROM E LINE SECTION 2:3, T 8 N, R i3 W A.S.P. PROPOSED LOCATION AT TOTAL DEPTH: 1480 FT. FROM S LINE AND 3236 FT. FROM E LiNE SECTION 23, T 8 N, R 13 W A.S,P. M650000ft8,506 .t Telecopy No. (907) 276-7542 August 23, 1988 ADMINISTRATIVE APPROVAL N O. 44.41 The application of SHELL WESTERN E & P, INC. to redrtll, complete, mhd produce the Middle Ground Shoal 18756 No. C-13-23 in the MGS "G:' Oil Pool in the Middle Ground Shoal Field. Mr. ]~I. L. Woodson Division Operations Manager Alaska Division Shell Western E & P, inc. 601 West Fifth Avenue, Suite 810 Anchorage, Alaska 99510 Dear Mr. Woodson, The referenced application was received on August 19, 1988 stating that the redrilling of the No. C-13-23 well is in the steeply dipping West Flank part of the field which requires closer than 80 acre areal well spacing to adequately drain this part of the reservoir. The Alaska Oil and Gas Conservation Commission has studied the evidence available and hereby authorizes the redrilling, com- pletion, and production of the referenced well pursuant to rule 6 of Conservation Order 44. SinTerely~j /' i' ~ /Lonnie C. ~mith Commissioner BY ORDER OF THE CO[~4ISSION dlf/3.AA44 ITEM APPROVE DATE (1) Fee ~P~ ~ (2 thru 8) (3) Adm n (9 thru (10 and 13) (4) Casg ~,~,~:~, ~-.~.QT~-~ (14 thru 22) (5) BOPE ~.~x~/~ f-~$B$ (23 thru 28) (29 thr~ 31') (6) Add: Geology: BEW Engineering: .cs rev: 08/11/88 6.011 1. Is uump~7 C3/4 Lr/--L-- the permit fee attached ...................................... .... Lease & Well No. YES NO 2. Is well to be located in a defined pool ............................. 3. Is well located proper distance from property line .................. 4. Is well located proper distance from other wells .................... 5. Is sufficient undedicated acreage available in this pool ............ 6. Is well to be deviated and is wellbore plat included ................ 7. 8. Is operator the only affected party ................................. xf/.~ Can permit be approved before fifteen-day.wait ...................... ~ . 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. For 29. 30. 31. 32. Does operator have a bond in force .................................. · Is a conservation order needed ...................................... Is administrative approval needed ................................... Is the lease number appropriate ..................................... ~ ......... Does the well have a unique name and number ......................... Is conductor string provided ........................................ ~/ Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water ..................... ~/~ ..... Is enough cement used to circulate on conductor and surface ......... ~ ....... Will cement tie in surface and intermediate or production strings ... /~ Will cement cover all known productive horizons ..................... -~ Will all casing give adequate safety in collapse, tension and burst.. -~ Is this well to be kicked off from an existing wellbore ............. . .. /~F Is old wellbore abandonment procedure included on 10-403 ............ , , Is adequate wellbore separation proposed ............................ ~ 52. Is a diverter system required ....................................... , Is the drilling fluid program schematic and list of equipment adequate//~. Are necessary diagrams and descriptions of diverter and BOPE attached. W~ . .. Does BOPE have sufficient pressure rating - Test to~/~ma~ psig .. ~ .. Does the choke manifold comply w/API RP-53 (May 84) .... Is the presence of H2S gas probable ................................. exploratory and Stratigraphic wells: Are data presented on potential overpressure zones? ................. Are seismic analysis data presented on shallow gas zones ............ If an offshore loc., are survey results of seabed conditions presented Additional requirements POOL INITIAL CLASS STATUS 0 ~-~0 mm Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history, file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. , No special effort has been made to chronologically organize this category of information. c~ LIS 'Tape Veri.£.icat. ic, n [,!st:i..r'q $C~!Umberqer AlasKa C[)?,~uti. nq Cer~i. Ler .[~,!C,,~IOPL. b? GP()tl:~,li') Sit0A[:,C13-23,50-733-20402 , ~':IDDI, E G[~'OLidD SHOAL,C1]-23,50-7]3 20402 P, iNC , . . . PAGE: RANGE: 1:3~,~ LiS ~'ar.e Yerif]cat;]on ~'fstin,7 StAir]mb. ether AlasKa Corr'out~tl~ Cent;er PAG~;: ~T~ V AT I {!{',J S KP: 105, Gl,: ,,.."'~',5I:?G !: 13 3/!i!~ ;a [;"'eli,l .::'p,,~., , D,F;PT}I. f~[': 1~!0. Ar:if}. .. L~C;:iKR ...... DEPTH [tF 1800 BT']' i3!ZF 1: !2,2a {~ 45. ~lJ[} RESISTIV.I.'F.~ FI'UTRATE RC$ISTTvT [~Y: ,~.507 ~ 63. O. 33t a 65. 29_. 3o ;)715 15i. 1188 F I E L, D CIS!i~G 11 o 5/8 ~ E~I'T SIZ~ 1: a,5 ~ 11221, PAGE: ~UD RF'._%TSTiV['!~~: 1.,']5 !f' 75. F'TL, q'~A'I~'',. RE$],.S'~: ~ T V'[FY.. ,,,' c,. .73 f~ 61,. [.,DP/,~N A: R. 7 -," A 9 ******************************************************************************** DAT~ 8A~,~PL~:[) EV,.;.!:RY -.50~0 FEET .5 * 5 .D T { !, {...'., T } I L 147 ", 10709 10 ~ g ~B. b - 1. 03 :l ~. 5 "'ii? (] O !.., 8 T t,.] C K 1 F,~ T H E l~'t O L, E ********************************************************************************* T~BLE TYPE T UNI V A L U D E F'I .................... ....... ............. ... ~ C 13-2 3 8TAT F'L ' ' ' .......... ' : SFCm 23 ( Schlumberqer Alaska Comp!~tinc..~ Center T!!r' 1 VA{.,U O~FI ...................................................................... . ............ ............. ~,. ~:~ ki T 0 w n s h i p . . ~ A ~,{c ~ .~ ~' Range !,~;c Longitude E~'~GI {-~q~AL FI'~E~YR gnginee~'s Name SON 73167 Service Order Number APlY 50-733-2u402 AP1 Serial Nu~nber INTER{4FiDI ~TE !P f)~,~CTI O~ Ter~5 ~ M U D ~' De l t8 Delta T Lont;~ TRANStT' Ft¢'~f] 2 TRAb;f;IT TRA~:SIT TI~4E S~)ontaneotls Potential ~8m~a R~V ~ l )' D' T ~'~{D RFiSIST!VT'rY NE:AD TEh~SiO ~ens J. ty PorOslrv Bulk l)er'~$ i t V r~ e 1 t a r h o Photo-Electric Factor OUALiTY C~'.~NTRO.I,, t3~"¢ S~.tORT SPACI~,¢L, tar ~.~Di Long t, onq ~r, per 1-2 ~indow Cot.~,r'~t ~ate (Llt!+t, U2) f..,onq Lower :,vine]ow Cot]nE Rate t<EAL DFiEt;' CO~,~DdCTIVITY QUAORAT~t. RF, DEEP CONDLiCT'IV!T'f $chlurnber':]er AlasKa r!o,~'~::,utti~,~ Cer:t:er LSHV !,o~rl LSRr4 ~,ong St2acin,_~ ~.~'Ta (~!ncorrectea~ [,IJR~ I,o~q iJpper ¢:~()~ ' " C~LJ Calit~er TfT~ S Tens j. oi~ H. TE~ HEAD PAGE: SFI, U DIL i')~ 54a6~0 07 220 9! ~ } · .t 4 68 0000000000 IbM f) Ib rlw¢4!:¢ 54862t) 07 i 20 ¥4 ILD OIL []I.~:~ 548680 07 120 4 6 0 1. SP nil 2¥ 54~t>Rn ()7 c)l 0 d~ 0 i i 618 0000000000 .......... as O6Ooooooo6 Schlumberger AlasKa Co~;:)dti~q Center PROCE$S· (HEX) I-r,'PF DIL (]il:,~i,~, S4[~o8o ,~,7 12n 46 0 i I t 4 68 0000000000 I~PF; 9IL ~1[( ~ ~: 54 ~ ~, a[m) ("7 1~(.) q4 0 1 1 I 4 6~ 0000000000 I~'R~ DII., ~.'~Z 5.!~5~u (~7 0~)n ('.,O O ! 1 I 4 68 0000000000 CIDP ~IL ~',.~,'HO ~,1~6~ 07 !.10 46 0 1 ! I 4 68 0000000000 (:!~P i')Ib ~,'~'.!~9 54~o~<) 07 lid 44 U 1 1 1. 4 6g 0000000000 IIRD DIb a~H[] 548~() 07 000 00 0 I 1 I 4 68 0000000000 IT~n [)I~, ~4~:-~() 54~o~o 07 OO0 ('~o 0 1 1 1 4 68 0000000000 I1.~~ DIL t,!~.~(~ 5,186~<, 07 000 O0 0 1 1 I 4 68 0000000000 (;P t',Ib (3AP! 5 ~ ~a ~',5 07 :ii~ ol 0 i 1, l 4 68 0000000000 TFNS 9ii, LR 542o~0 ()7 63S 21 O 1 1 1 4 68 0000000000 ~'~q'E~:' OIL ,)~:(;F 54ai:,~0 07 (.~,~(, O0 0 1 1 1 4 68 0000000000 ~FE:$ OI5 ,:)U~.,~? 54;:~5P~) 07 000 O0 0 I I 1 4 68 0000000000 ~ITEY 9IL L,B 54~o~0 ~;7 090 00 t) 1 ! 1 4 68 0000000000 DT ~.., 8 S ijS/F 54~,3~(1 (~7 5~u ~0 0 l. 1 I 4 6~ 0O00000000 TT1 LSS LIS ~4~680 t)7 522 a3 0 1 I 1 4 68 0000000000 TT2 LSS (iS 54~b~0 (:)7 522 93 0 1 1. 1 4 68 0000000000 TT3 LSS [.1~ 549620 07 522 83 o i 1. 1 ~ 68 0000000000 TT4 LSS t~$ 54R~o 07 522 R3 O I ~. I 4 ~8 OO00000000 SP bSS ~'~V 548680 07 010 01 u l I I 4 68 0000000000 GP LSS GAP] 5~86~t) 07 '~I~'' 01 {3 i 1 4 fi8 O0000OO000 TFN8 LSS LB 54a680 07 635 21 o I 1 4 68 0000000000 MT[;:~'~ !.,~88 DE:;F 54:~6~) 07 000 oO (? I ! I 4 6~ O00000000O ~RE8 LS:S OH*IN 54R690 07 000 O0 0 I 1 I 4 68 0000000000 H~'E~,~ USS !.,~ 549(~0 o7 ()0o nO 0 1 ! t 4 6~ 0000000000 DPHT I.,DT PI.) S,%~6~<) 45 890 01 0 i t I 4 ~8 ' 0()00000O00 ~O~ LD'C <;/C3 548b~U 45 35t) 02 () i 1 1 4. 68 0000000000 D:~HO b[)T G/C3 ~-,,~b~, 45 358 01 0 i i 1 4 0000000000 P~F LOT ~hP<) ,45 35~ <:'J 0 I ~ 1 4 b8 0000000000 OLS bDT 5!868() ~5 3~4 (>l. 0 I I I 4 6B 0000000000 0 $ S [., D T ~i 4 ~ 0 ~ n a 5 354 () i i) ~ ! I 4 6 B 0000000000 LS LDT CPS 54868c) 45 354 01 0 1 1 I 4 68 0000000000 LU bom CPS 548bg:o a5 354 (',1 0 I I 1 4 ~8 0000000000 L[ ~,DT CPS 5486~0 45 3~.4 0 J~ 0 ~ 68 0000000000 L!Ta LOT CPS 54ab~0 45 354 01 0 i 68 0000000000 ,SS1 bDT CPS 54~680 45 354 02 LSHV BDT V 54~680 45 354 OO SS~V hD~ v 54~680 45 B54 0u SIRH BDT G/C3 548680 45 350 02 LSR,t~ gDT C/C3 54~6Ri~ 45 35~''~ 02 C ~ L f ~] b T :[ f,¢ 5486 ~ ¢'"} 45. 2 S 0 o 1 ~TE LOt {.,EGF 54868n HTEN LDT 0 000 00 0 0 f) 0 c) O 0 I 4 68 0000000000 4 68 0000000000 4 :: '68 000000000,0 4 68 0000000000 68, 00::000.00000 6:~ 0000000000 4 68' ~00:0'00:0:0000 4 68 0000000000 4 68 O00 O ( chlumber~r A!es<a Como .tjr,<] Center [)ir_pT, 11279. CIDP PIl, -9o9. II~:DIL -999.25() ' PHO. !...~DT -999,25{) ~;F:F, bDq' LS. I.OT -999. 250 LU. I,DT S1RH.LDT -909.2E{) GP,[,DT -90o' 2h,~ TEk, S,bDT HTEN, LD~ -909,250 DFPT. I 1200.00u SFLtl. DZ L, CI. OD nil 70,3t3 CI~P,Di'L ,,., .DIL 0,323 TT1. LSS 9~6.0Or) TT2 ~t~ES. LSS O. 32 3 D~H'O' LDT -99u.250 PEF', ........ ~. . SS 1. LDT -909' 250 8 ! RN, !,0T -999. 250 1.8~.~, LDT GN LDT -9q9.250 TF'NS LDT HTE~,: ~ LDT -909. ~ 50 D Fi p T l 10 O0. O 00 o I~ .L I': ' D lI C:IDP,, ... ]..:L ' " '" 16,109 !I~.DIL 24 2O3 G~.bIL ~ R E g. D I [, o ' TT1,LSS 766,500 T'r2 ~.Yqq ~,: P ES. T_,sS o, .~ 13 iiT ~::.:; ' b88 -999.2b0 1L~-',. ~) I b lc)-g9.2bO ILD.DIL -999,250 [ [v.:pf{. D fh -999 250 IFRE, Dllb '990.250 llR[),t)Ib 999'250 IIXD.DIL -999,250 ;? El N tJ, L) I' b :999~250 aTE~.DII, '999,250 DT, I~SS B0000 DTL. LSS 772.000 TT3 6S8 1086'000 TT4 LSS -. IENo. USS 5192,000 ~TEM, LSS -444,500 [)P~I,SDT -999.250 RNOB.LDT -999,2b0 OLS.Li)T q99,250 QSS'LDT -999,250 [.,b, LDT :599,250 BITH.LDT -999,25o LSHV,LDT 999,250 SSHV,LDT -999,250 LURM,bOT ~99g,250 CALl.BDT 'q9°.250 ~;,TE~ ' ' ,bDI '999.250 ~RES,LDT 19.266 I.L~. OIL 17 172 I!.,D. DI L 14.211 ,i~PH. OIL 17:609 IFRF DIL 56.719 !IRD.DIL 65.125 IIXD,DIL 40.003 T ~:~]'~ . [) I[o 8048 000 ~ITE~. DIL 271. ' 250 DT. LSS 80:000 DTL. LSS 772,000 ..?~"3,LS~ 1086,000 TT4,55S oqQ,25O ~{ ~,E~ ·I-'UT -~99'25~ ca~l.~bT , LOT -9991 250 MRES 27 108 24o .i o. 7 ,:.t, 20 3,375 ILM- Din ~n ", · ,,, ,., ::4 TE;NS,bSS 7892 O0 ' ' ' -999,250 -999.250 1999.250 -999,250 77,000 938,000 169,250 '999.250 '999,250 -999.250 -999.250 '999,250 '999.250 13.781 20,000 9,016 169 250 77 000 938 000 169 25 -999 25i -999 25 -999 250 ~999~250 999.250 19 109 20 )0 16~ 72 86.I. 169 2 0 7~ i88 132 o0o $ 0 59.3 3 20'0(~0 62 765 1:6 2 LIS $cl, lU~-~berqer AlasKa CoF, Putini..~ Cert, e~ iiTE:N. L[)T -56,0 ~ ] CIDP.DII, 17.641 C I~ P. l','r l.~ IIR~:. L)IL 23.57~ (;R. M [' ~j b, n I L 0.315 H T E ?.~. r, 1 L .. ,.,., 22¢.g75 iu.bbT SSi .I,D~ I°9.75[-' GP.LDT 50,3~5 ~[<MS. !,pT I.) F p T. I c 8 O 0. t:' ¢; t; S F' B U. 0 f .L. u, , I!._, 17,,~1'J "'"' '" R~". D:IL 20,453 GR' " - . . D I TTI LS8 777.50o TT2,LSS SP I, S5 -41 c~63 GR I ' .... " m · S ..4 . Lc Lo~ t).324 HTE~,~.b . L_..T 2.'i , ........ ~ . 0o2. Sl RF~, Lbq 2.3~5 HTE .LDT 13I.DOU 1 (}700,000 o~ LU, 1,..][ ~ 19,64! CI~P.D'Ib 30,547 (;R,i31I; -9q9,2~f .. ' 13BT - 99 9,25 () 1., ~!. t.., F)T -999,250 SS2,LgT . ..... .~,250 l .... F:S,LBT -999,250 i O-~AR-19~9 14:39 PAGE: 2,725 ~Lb, LDT 206. 750 I.,h. bPT 280,0uo I..5}IV LI'"' 2 , 566 [URH , 78bO, 000 gTEr~, BDT 0.024 112.625 12i7.000 2'580 169.000 QSS,LDT LITH.LDT SSHV,LDT CAL[.LDT 0,005 59,531 1327,000 8,969 0,313 b2,000 ILM,DIL 56,625 T ~-~ P ~ "IL 23.~7 IIRO,I}IL 43. 594 TENS. USS 402.500 .raPE I . LDI' 2,531 0[.5. bDT 221 , 125 [.L, , bDT 28~.750 LSHV,LDT 2.53! L~P?i. LF)T 8o24. OOO 40.313 42.8'15 16,828 8160.000 ~4.000 R66.500 H160.000 6.404 0 010 1 7: 5o I217,000 2.533 169.625 ILD,DIL IFRE,DIL IIXD,DIL MTE~.DIL OIL,L$$ TI'4,LSS RHOB.LDT QSS.LDT LITH,LDT SSHV.LDT CALI.LDT MRES.LDT 52.469 20.000 4.652 169.750 64.125 742.500 169.750 2.544 O.u13 60,563 1327 o00 9!383 0 316 36. 156 I I,~. 58 0~0 IMPH. 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