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Home My WebLink About181-0991. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Suspended Well Inspection Development Exploratory 3. Address: Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 10,904 feet 4,688 feet true vertical 10,783 feet 10613 (fill) 4719 (fish)feet Effective Depth measured 4,688 feet N/A feet true vertical 4,687 feet N/A feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth) 2-7/8" 6.5# L-80 2,002' MD 2,002' TVD 10,418' MD Packers and SSSV (type, measured and true vertical depth) Anchor 10,310' TVD N/A N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: 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: Authorized Name and Digital Signature with Date: Contact Name: Daniel Taylorr, Optimization Engineer Contact Email:dtaylor@hilcorp.com Authorized Title: Contact Phone: 907-947-8051 TVD 3,400psi 3,130psi 6,020psi 3,354' 3,354' Burst Collapse 1,580psi measured Packer Plugs Junk measured Length measured true vertical Production Liner 10,442' 656' Casing Structural 10,343' 5-1/2" 10,452' 10,902' 10,781' 72'Conductor Surface STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 181-099 50-133-20344-00-00 3800 Centerpoint Drive, Suite 1400 Anchorage, Alaska 99503 Hilcorp Alaska, LLC N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: FEDA028997 Swanson River Field / Hemlock Oil Soldotna Creek Unit (SCU) 31-08 MD 0 Size 72' 0 00 0 00 0 9,190psi 7-5/8" Intermediate 20" 10-3/4" 40' 3,354' N/A Sr Pet Eng: 8,830psi Sr Pet Geo: Sr Res Eng: WINJ WAG 0 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Noel Nocas, Operations Manager 907-564-5278 N/A Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf p k ft t Fra O s Ot 6. A G L PG , Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Grace Christianson at 3:48 pm, Jul 30, 2025 Digitally signed by Noel Nocas (4361) DN: cn=Noel Nocas (4361) Date: 2025.07.28 16:03:50 - 08'00' Noel Nocas (4361) BJM 9/25/25 Updated by DMA 11-16-18 Soldotna Creek Unit Well SCU 31-08 Completion Ran: 2/27/2013 PTD: 181-099 API: 50-133-20344-00 SCHEMATIC PBTD = 4,688 MD; 4,687 TVD TD = 10,904 MD; 10,783 TVD MAX HOLE ANGLE = 17 deg RKB = 19.50 / GL = 128 AMS CASING DETAIL Size Wt Grade Conn ID Top Btm 20 94# H-40 - 19.124 Surface 72 10-3/4 40.5# K-55 - 10.050 Surface 3,354 7-5/8 33.7# S-95 - 6.765 Surface 7-5/8 26.4# N-80 - 6.969 7-5/8 29.7# N-80 - 6.875 10,452 5-1/2 20# N-80 - 4.778 10,246 10,902 TUBING DETAIL 2-7/8 6.5# L-80 EUE 8RD 2.441 Surface 2,002 JEWELRY DETAIL No. Depth Length ID OD Item 1 19.5 0.66 2.441 Tubing Hanger 2 4,698 Composite Plug w/10 cement @ 4,688 10-25-18 1 H8 H8 H10 H8 G1 H1 H2/3 H4/5 7-5/8 20 10-3/4 5-1/2 NOTE: The Surface Casing annulus was used to down squeeze the liner lap during the 1986 workover of this well. Liner Top 10,246 H6 H8 Tag Fill @ 10,613 Sand & Perf Debris 5/14/18 G2 PERFORATION HISTORY (DIL) Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt spf Comments Date G1 10,374 10,384 10,267 10,277 10 6 2 PJ HC, 60 deg 4/5/2001 G2 10,407 10,435 10,145 10,173 28 6 2-7/8 HC, 60 deg 5/14/18 H1 10,442 10,448 10,333 10,339 6 6 3-3/8 HC 60 deg 2/27/13 H1 10,445 10,451 10,336 10,342 6 6 2 PJ HC, 60 deg 4/5/2001 H2/3 10,467 10,515 10,357 10,404 48 6 2 PJ HC, 60 deg 4/5/2001 H2/3 10,469 10,514 10,359 10,403 45 6 3-3/8 HC 60 deg 2/27/13 H4/5 10,532 10,580 10,420 10,467 48 6 3-3/8 HC 60 deg 2/27/13 H5 10,534 10,565 10,422 10,452 31 6 1-11/16 HC 11/5/1999 10,565 10,580 10,452 10,467 15 4 1-11/16 HC 2/23/1998 H6 10,596 10,610 10,482 10,496 14 4 2-1/8 Enerjet 6/8/1995 H8 10,616 10,634 10,502 10,519 18 4 2-18/ DA Slimkone 5/10/1983 6 3-3/8 Baker TCG 8/4/1986 H8 10,664 10,672 10,549 10,556 8 4 2-18/ DA Slimkone 5/10/1983 6 3-3/8 Baker TCG 8/4/1986 H8 10,695 10,703 10,579 10,587 8 4 2-18/ DA Slimkone 5/10/1983 4 3-3/8 Baker TCG 8/4/1986 H8 10,706 10,710 10,590 10,593 4 4 2-18/ DA Slimkone 5/10/1983 6 3-3/8 Baker TCG 8/4/1986 H10 10,726 10,732 10,609 10,615 6 4 2-18/ DA Slimkone 10/7/1982 6 3-3/8 Baker TCG 8/4/1986 TOF 4,719 6-4-18 Fish Details: 19 jts of dropped 2-7/8 tubing (expected corkscrewed), seat nipple, tubing anchor, desandor/degasser, mud joints and unloader valve. 2 TOC 4,688 10-25-18 Suspended Well Inspection Review Report Reviewed By: P.I. Suprv Comm ________ JBR 09/09/2025 InspectNo:susSTS250724133702 Well Pressures (psi): Date Inspected:7/17/2025 Inspector:Sully Sullivan If Verified, How?Other (specify in comments) Suspension Date:10/26/2018 #318-440 Tubing:70 IA:45 OA:0 Operator:Hilcorp Alaska, LLC Operator Rep:Jesse Katzenberger Date AOGCC Notified:7/15/2025 Type of Inspection:Subsequent Well Name:SOLDOTNA CK UNIT 31-08 Permit Number:1810990 Wellhead Condition clean and valves turned easily Surrounding Surface Condition clean and free of debris. No subsidance Condition of Cellar there was 1/2" or so of water at the bottom that was clear and sheen free Comments location verified by plot and signage Supervisor Comments Photos (4) attached Suspension Approval:Sundry Location Verified? Offshore? Fluid in Cellar? Wellbore Diagram Avail? Photos Taken? VR Plug(s) Installed? BPV Installed? Tuesday, September 9, 2025 9 9 9 9 9 9 9 9 9 2025-0717_Suspend_SCU_31-08_photo_ss Page 1 of 2 Suspended Well Inspection – SCU 31-08 PTD 1810990 AOGCC Inspect # susSTS250724133702 Photo by AOGCC Inspector S. Sullivan 7/17/2025 2025-0717_Suspend_SCU_31-08_photo_ss Page 2 of 2 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS OCT 17 2019 AOGCC 1. Operations Abandon LJ Plug Perforations Ll Fracture Stimulate LJ Pull Tubing Li Operations shutdown Li Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: Suspended Well Inspection Q 2. Operator Hilcorp Alaska, LLC 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development Ex lorato P ❑ P ry ❑ Stratigraphic❑ Service ❑ 181-099 3. Address: 3800 Centerpoint Dr, Suite 1400 Anchorage, 6. API Number: AK 99503 50-133-20344-00-00 7. Property Designation (Lease Number): 8. Well Name and Number: FEDA028997 Soldotna Creek Unit (SCU) 31-08 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A Swanson River Field / Hemlock Oil 11. Present Well Condition Summary: Total Depth measured 10,904 feet Plugs measured 4,688 feet true vertical 10,783 feet Junk measured 10613 (fill) 4719 (fish) feet Effective Depth measured 4,688 feet Packer measured N/A feet true vertical 4,687 feet true vertical N/A feet Casing Length Size MD TVD Burst Collapse Structural Conductor 40' 20" 72' 72' Surface 3,354' 10-3/4" 3,354' 3,354' 3,130 psi 1,580 psi Intermediate Production 10,452' 7-5/8" 10,452' 10,343' 6,020 psi 3,400 psi Liner 656' 5-1/2" 10,902' 10,781' 9,190 psi 8,830 psi Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic Tubing (size, grade, measured and true vertical depth) 2-7/8" 6.5# L-80 2,002' MD 2,002' TVD 10,418' MD Packers and SSSV (type, measured and true vertical depth) Anchor 10,310' TVD N/A N/A 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 1 0 0 0 0 1 0 Subsequent to operation: 0 0 0 0 10 14. Attachments (required per20 AAC 25.070, 25.071, a 25.283) 15. Well Class after work: Daily Report of Well Operations 0 Exploratory E] Development Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil El Gas Li WDSPL Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP Q SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Authorized Name: Bo York 777-8345 Contact Name: Ted Kramer Authorized Title: Operations Manager tkramerCoihilcoro.com Contact Email: Authorized Signature: - , --�— Date: 1 7l) L F Z 5 Contact Phone: 777-8420 Form 10-404 Revised 4/2017/Y J��0t' -4 l� 5 =��-1' RBDMS�OCT 2 21019 Submit Original Only A State of Alaska Oil and Gas Conservation Commission IF --- Defidency Report Location: SCv 31-"6 J-14 lel Date: lya Io -S-1 PTD: 1 81- tit} Operator: Type Inspections rOEp WbC� Operator Rep: position: S R Pkty c � tLrn eot-etw CL V1 Op. Phone: �j O 2 - -z v S - 25 I Correct: by (date): Op. Email: �J I e ��Nuv l ft I c ^ Follow Up Req'd: !� t Detailed Description of Deficiencies -7i OIL Date Corrected LC,*,4 .szow� Ecw� A.ro ter,-�a�t VAWG r� O f�irura s -ra A oC-,CC O•�►afE------- —.__._. -- AttaciFig-ninga SigvC2 /fj/,s 1 Operator Rep Rir+a�Lx9 O-°Afterscopyofthisformisto eleftwiththeope or. Fot1oW-up Instructions Return a copy of this Deficiency Report to AOGCC (Attention: Inspection Supervisor) within 7 days of receipt. Include the "Date Corrected" and attach supporting documentation for each corrective action implemented to address the deficiencies. if a follow-up inspection was performed by AOGCC, include the date and name of Inspector. Extensions for corrective actions taldng longer than the "correct by" date must be requested and accompanied byiustification (Attention: Inspection Supervisor). Documentation of def clences that are outside of AOGCC regulator/ jurisdiction will be forwarded to the appropriate authority for follow-up action. Revised 2/2016 Soldotna Creek Unit �. Well SCU 31-08 Ran: 2/27/2013 SCHEMATIC PTD: P181-099 IDRorn aa: API. 5G-133-20344-00 RKB= 19.50'/GL=128'AMS 20" CASING DETAII TUBING DETAIL 10-3/4" 1 2-7/8" 16.5# L-80 EUE 8RD 2.441" Surface 2,002' 10-25-18 2 TOF 4,719' Liner Top 6-4-18 10,246' G1 G2 H1 7-5/8" H2/3 H4/5 Tag Fill @ 10,613' H6 Sand & Perf Debris 5/14/18 {;{rte .PP H8 HS H8 H8 H10 5-1/2" PBTD = 4,688' MD; 4,687' TVD TO = 10,904' MD; 10,783' TVD MAX HOLE ANGLE = 17 deg Fish Details: 19 its of dropped 2-7/8" tubing (expected corkscrewed), seat nipple, tubing anchor, desandor/degasser, mud joints and unloader valve. IEWELRY DETAII No. Depth Len h ID Wt Grade Conn ID Top Btm FSize 20" 94# H-40 19.124" Surface 72' 10-3/4" 40.5# K-55 0.050 1 Surface 3,354' 7-5/8" 33.7# 5-95 6.765" Surtace 28' 7-5/8" 26.4# N-80 H1 10,442' 10,448 7-5/8" 29.7# N-80 - 6.875" 3-3/8" HC 60 deg 10,452' 5-1/2" 20# N-80 4.778" 10,246' 10,902' TUBING DETAIL 10-3/4" 1 2-7/8" 16.5# L-80 EUE 8RD 2.441" Surface 2,002' 10-25-18 2 TOF 4,719' Liner Top 6-4-18 10,246' G1 G2 H1 7-5/8" H2/3 H4/5 Tag Fill @ 10,613' H6 Sand & Perf Debris 5/14/18 {;{rte .PP H8 HS H8 H8 H10 5-1/2" PBTD = 4,688' MD; 4,687' TVD TO = 10,904' MD; 10,783' TVD MAX HOLE ANGLE = 17 deg Fish Details: 19 its of dropped 2-7/8" tubing (expected corkscrewed), seat nipple, tubing anchor, desandor/degasser, mud joints and unloader valve. IEWELRY DETAII No. Depth Len h ID OD Item 1 19.5' 0.66 2.441 Btm(ND) Tubin Hanger 2 4,698' Comments Composite Plug w/10' cement @ 4,688' 10-25-18 PERFORATION HISTORY (DIL) Zone Top(MD) Btm MD) Top(TVD) Btm(ND) Amt spf Comments Date G3 10,374' 10,384' 10,267' 10,277' 10' 6 Y' PJ HC, 60 deg 4/5/2001 G2 10,407' 10,435 10,145' 10,173' 28' 6 2-7/8" HC, 60 deg 5/14/18 H1 10,442' 10,448 10,333' 10,339' 6' 6 3-3/8" HC 60 deg 2/27/13 Hl 10,445' 10,451' 10,336' 10,342' 6' 6 2"PJ HC, 60 deg 4/5/2001 H2/3 10,467' 10,515' 10,357' 10,404' 48' 6 2" PJ HC, 60 deg 4/5/2001 H2/3 10,469' 10,514' 10,359' 10,403' 45' 6 3-3/8" HC 60 deg 2/27/13 H4/5 10,532' 10,580' 10,420' 10,467' 48' 6 3-3/8" HC 60 deg 2/27/13 H5 10,534' 10,565' 10,422' 10,452' 31' 6 1-11/16" HC 11/5/1999 10,565' 10,580' 10,452' 10,467' 15' 4 1-11/16" HC 2/23/1998 H6 10,596' 10,610' 10,482' 10,496' 14' 4 2-1/8" Enerjet 6/8/1995 H8 10,616' 10,634' 10,502' 10,519' 18' 4, 2-18/"DASlimkone 5/10/1983 6 3-3/8" Baker TCG 8/4/1986 72' 10,549' 10,556' 8' 4 2-18/"DASlimkone 5/10/1983 6 3-3/8" Baker TCG 8/4(1986 3' 10,579' 10,587' 8' 4 2-18/"DASlimkone 5/10/1983 ME 4 3-3/8" Baker TCG 8/4/1986 0' 10,590' 10,593'F66' 4 2-18/"DASlimkone 5/10/1983 6 3-3/8" Baker TCG 8/4/1986 2' 10,609' 10,615' 4 2-18/"DASlimkone 10/7/1982 6 3-3/8" Baker TCG 8/4/1986 F: The Surface Casing annulus was used to down squeeze the ap during the 1986 workover of this well. Updated by DMA 11-16-18 14 Hilcorp Alaska, LLC SOLDOTNA CREEK UNIT 31-08 (SCU 31-08) API # 50-133-20344-00 00 PTD # 181-099 LEASE # FED A028997 SURFACE LOCATION: SW1/4, NE1/4, SEC 8, WN, R9W, SM, AK M v 'T 57 livil] YaA wi-4-21valiA 1 WA 1 'a a R ! 0 R � O +` w ♦� . 1 n,a ' Wit•`_' 1 i - 1e- . Regg, James B (CED) <Sc � 2 From: Taylor Malone <tmalone@hilcorp.com>0<�?O Sent: Monday, October 14, 2019 4:29 PM To: Bixby, Brian D (CED); Regg, James B (CED) Cc: Bruce Hershberger, Daniel Paulk; Donna Ambt..� Subject: SCU 31-08 suspended well inspection Attachments: 20191014_160112_resized.jpg; 20191014_160423_resizedjpg; 20191014_160546 _resized.jpg; 20191014_160604_resizedjpg; 20191014162350490.pdf Hello Jim, Please see the attached requested photos from the suspended well inspection on SCU 31-08. Let me know if you have any questions or if there is any more required information needed. Thanks, Taylor Malone Swanson River Lead Operator 90y7.283.2543 [I ilcorp, Alaska Alternate: Dpaulk@hilcorp.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, opening or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. State of Alaska Oil and Gas Conservation Commission Deficiency Report =iiosc "CU3i' Date: PTD: I W1-099 Opera Lot: lsll`Cc-.W A .4 Typelnspection5 `•L. Operator Rep:- 1^ r Inspector��t�g In �� positio�r sa- P� ( G _OyOf'2.W10.h no. Phone: Qj p ) - Correct by (date): I0-19-19 II Op- Email: Follow Up Req'd: SENrl��TO.� s Detailed Description of Deficiencies 61L Date Corrected f�PN' .1Zo.�n. E��►C f��r?+r, Aa VAWG i (,o, L _ o,� rN �-� ✓„�„�.-- 10h 201 '� „� c i�-Nuro S 'r'o fa OC-tCC O••�E__� Attachments: Signatures: ` ��^`� /474e/9 Operator Rep After signing, a copy of this form is to he left with the ope tor. Follow-up Instructions Return a copy of this Deficiency Report to AOGCC (Attention: Inspection Supervisor) within 7 days of receipt. Include the "Date Corrected" and attach supporting documentation for each corrective action implemented to address the deficiencies. if a follow-up inspection was performed by AOGCC, Include the date and name of Inspector. Extensions for corrective actions taking longer than the "correct by" date must be requested and accompanied byjustification (Attention: Inspection Supervisor). Documentation of denciences that are outside of AOGCC regulatory jurisdiction will be forwarded to the appropriate authority for follow-up action. Revised 7/70:1.6 Deficiency Corrective Actions Photos — SCU 31-08 (PTD 1810990) Photos courtesy of Hilcorp Alaska LLC 10/14/2019 Photos document corrective actions in response to AOGCC Deficiency Report (Oil in Well Cellar; Missing Valve Handle); issued during Suspended Well Inspection 10/5/2019 2019-1014_Deficiency_SCU_31-08_corrective-a ctio ns_p hotos.docx Page 1 of 2 Well Sign Valve handle installed on m aste r va Ive Oil in well cellar removed (no sheen) 2019-1014_Deficiency_SCU_31-08_corrective-actions_photos.docx Page 2 of 2 I CEq� WE D STATE OF ALASKA 'DEC 1 8 2013 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AN 1a. Well Status: Oil ❑ Gas El SPLUG ❑ other ❑ Abandoned ❑ Suspended0. ib. WeII Class: 20AAC 25.105 20AAC 25.110 Development El Exploratory ❑ GINJ ❑ WINJ ❑ WAG❑ WDSPL ❑ No. of Completions: Service EJStratigraphic Test F]2. Operator Name: 6. Date Comp., Susp. or 14. Permit to Drill Number / Sundry: Hilcorp Alaska, LLC �,, . 3. Address: ••_...... •"•� •IVI IaIO-44V 7. Date Spudded: 15. API Number: 3800 Centerpoint Dr, Suite 1400, Anchorage, Alaska 99503 6/26/1982 50-133-20344-00-00 ' 4a. Location of Well (Govemmental Section): 8. Date TD Reached: 16. Well Name and Number: Surface: 1902' FNL, 1968' FEL, Sec. 8, T7N, R9W, SM 8/23/1982 Soldotna Creek Unit (SCU) 31-08 Top of Productive Interval: 9. Ref Elevations: KB: 155' . IT Field / Pool(s): 1269' FNL, 1968' FEL, Sec. 8, T7N, R9W, SM GL: 128' • BF: Swanson River Field / Hemlock Oil Total Depth: 10. Plug Back Depth MD1TVD: 18. Property Designation: 1213' FNL & 1308' FEL, Sec. 8, T7N, R9W, SM 4,688' MD / 4,687' TVD FEDA028997 ' 4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth MD/TVD: 19. DNR Approval Number: Surface: x- 340373 ' y- 2454131.8 - Zone- 4 '10,904' MD / 10,783' TVD • N/A TPI: x- y- Zone- 12. SSSV Depth MD/TVD: 20. Thickness of Permafrost MD/TVD: Total Depth: x- 340425.5 y- 2454131.2 Zone- 4 N/A N/A 5. Directional or Inclination Survey: Yes LJ (attached) No 13. Water Depth, if Offshore. 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic and printed information per 20 AAC 25.050 N/A (ft MSL) N/A 22. Logs Obtained: List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page if necessary N/A 23. CASING, LINER AND CEMENTING RECORD CASING WT' PER GRADE SETTING DEPTH MD SETTING DEPTH TVD AMOUNT FT. TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 20" 94# H-40 Surf 72' Surf 72' Driven 10-3/4" 40.5# K-55 Surf 3,354' Surf 3,354' 14-3/4" 1490 sx Class G 7-5/8" 33.7# S-95 Surf Surf 9-7/8" 800 sx Class G 7-5/8" 26.4# N-80 9-7/8" 7-5/8" 29.7# N-80 10,452' 10,343' 9-7/8" 5-1/2" 1 20# 1 N-80 10,246' 10,902' 10,143' 10,781' 6-5/8" 86 sx Class G 24. Open to production or injection? Yes ❑ No EJ 25. TUBING RECORD If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation SIZE DEPTH SET (MD) PACKER SET (MD/TVD) Size and Number; Date Perfd): 2-7/8" 2,002' N/A 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes No LJ Per 20 AAC 25.283 (i)(2) attach electronic and printed information DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production: Method of Operation (Flowing, gas lift, etc.): N/A N/A Hours Tested: Production for Oil -Bbl: Gas -MCF: Water -Bbl: Choke Size: Gas -Oil Ratio: gDateTest: Test Period bing Casing Press: Calculated Oil -Bbl: Gas-MCF:Water-Bbl: Oil Gravity -API (corr): 24 -Hour ate Form 10-407 Revised 5/2017 CONTINUE PP_0 RBQ�� Submit ORIGINIALo? /q L 1 2018 _/� /, iiia U 28. CORE DATA Conventional Corals): Yes ❑ No 0 . Sidewall Cores: Yes ❑ No Q - If Yes, list formations and intervals cored (MDfTVD, Fromlro), and summarize lithology and presence of oil, gas or water (submit separate pages with this form, if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No ❑✓ If yes, list intervals and formations tested, briefly summarizing test results. Permafrost - Top Permafrost - Base Attach separate pages to this form, if needed, and submit detailed test Top of Productive Interval information, including reports, per 20 AAC 25.071. Formation at total depth: 31. List of Attachments: Operations Summary, MIT, Schematic Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, paleontological report, production or well test results, per 20 AAC 25.070, 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name: Chad Helgeson Contact Name: Ted Kramer Authorized Title: Operations Manager Contact Email: tkramer&1).hilcoro.com Authorized Contact Phone: 907-777-8420 Signature: Date: ill -2 1/17 INSTRUCTIONS General: This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item 1 a: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 1 b: Well Class - Service wells: Gas Injection, Water Injection, Water -Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Item 4b: TPI (Top of Producing Interval). Item 9: The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 19: Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY -123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. Item 20: Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31: Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. orm 10-407 Rev{seo b¢ut 7 Submit ORIGINAL Only Hilcorp Alaska, LLC Well Operations Summary Well Name Rig AN Number Well Permit Number Start Date End Date SCU 31-08 50-133-20344-00 181-099 10/22/18 10/26/18 Daily Operations: 10/22/2018 - Monday Reviewed JSA, discussed daily work plan and multiple work teams, reviewed hazards and mitigations. Start equipment and prepare to begin daily operations. Weatherford on location to change from 3-1/2" Center Bore Rams to 2-7/8" Center Bore Rams, Could not initially get ram door bolts out, this caused a delay in operations from 07:00 through to 13:00, at 13:00 all bolts were out and rams were changed out. During this time we began moving equipment into location, bled pressure from well, installed a 2 way check, nippled down tree and started spotting in equipment. Nipple up BOP's, Move in rig and support equipment, spread herculiner, spot equipment and began rigging up, all equipment spotted in, rig stood up and guyed out, ready for BOP test at 12:00 noon tomorrow. 10/23/2018-Tuesday Reviewed JSA, discussed daily work plan, associated hazards and mitigations, discussed Swanson River Fields speed limits and driving habits. Start equipment, check well pressures (10 PSI on Tubing, 15 psi on casing), prep to finish rig up. Finish rigging up equipment and prepare to begin Initial BOP rig up. Perform Initial BOP pressure test and H2S and LEL monitor testing, All systems passed pressure test. Rig up tubing handling equipment on floor, make up landingjoint and prepare to POOH with hanger, Made up FOSV on landing joint, backed out lock down pins, bled pressure from the annulus and tubing, unlanded tubing (27,000 up weight, 29,000 traveling weight) pulled hanger to the floor and removed hanger, Made up FSV, closed FSV, Pipe rams, checked all valves on well head and BOP stack to insure well was secure SDFN. 10/24/2018- Wednesday Start equipment and prepare to begin daily operations. After starting the generator, it died a few minutes later, mechanic worked on generator to get it up and running again. Found fuel filter to be plugged solid due to unknown substance. Could not begin operations due to the generator supplying the power needed to run the accumulator for the BOP'S. Prep floor and tubing handling equipment to begin POOH. POOH with 76 single joints of tubing and stood back 32 stands, well is ready to run a Composite Bridge Plug and dump bail cement. Service and fuel equipment prepare for early morning start up. Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date SCU 31-08 J v ( 50-133-20344-00 1 181-099 10/22/18 10/26/18 Daily Operations: 10/25/2018 - Thursday Reviewed JSA and Daily work activities and associated hazards. Rig up E -Line and RIH with 6.25 GR/JB, Tagged up at 4,720' Top of Fish, POOH. Waiting to make adjustments to CBP sheer screws that were the wrong size. Rig up and RIH to set CBP, set CBP at 4,698', moved plug up 2' due to collar at 4,704' to insure plug was not set in collar. POOH. Mix cement kits, rig up to RIH with Bailer and cement, mixed 20 gallons, 10" of cement, RIH and dumped cement on top of plug set 4,698', putting TOC at 4,688'. POOH and rig down. Pumped 100 BBLs down casing to start fill up and help to have fluid level above the EOT before pumping freeze protect on well.RIH with 2-7/8" EUE 8RND Tubing, ran a total of 63 Joints, 2,001.8', 31.77 Joint Average. Pump 50 additional bbls to insure that fluid would now be above the EOT, pump 25 Gallons of freeze protect fluid down tubing and 25 bbls down casing. Land tubing in hanger, hanging weight 15,000#'s. Nipple around BOP's and well head, tested voids, secured well and location, fueled equipment and SDFN. 10/26/2018 - Friday Reviewed JSA, discussed daily work plan, reviewed associated hazards and mitigations. Prep equipment for pressure test of casing, continue rigging down equipment and preparing for move to new well. Start pressure testing, found production casing valve leaking through stem, had to change valve out and make up flanged connections on new valve, with valve changed out ready to begin pressure testing again. Filled the well with test pump after running out of water in pits. Finished fill up and brought pressure up to 1,500 psi, held solid for 45 minutes. Finished rig down and moved equipment up to SRU 234-15. og IN 'J.0 , Hileore RKB= 19.50'/GL=128'AMS TOC 4,688' 10-25-18 TOF 4,719' 6-4-18 Tag Fill @ 10,613' Sand & Perf Debris 5/14/18 SCHEMATIC Soldotna Creek Unit Well SCU 31-08 Completion Ran: 2/27/2013 PTD: 181-099 apH sn_133.7n�aa_nn CASING DETAIL Size Wt Grade Conn ID Top Btm 20" 94# H-40 19.124" Surface 72' 10-3/4" 40.5# K-55 - 10.050" Surface 3,354' 7-5/8" 33.7# S-95 - 6.765" Surface 10-3/4" 7-5/8" 26.4# N-80 - 6.969" 10,442' 10,448 7-5/8" 29.7# N-80 6.875" 3-3/8" HC 60 deg 10,452' 5-1/2" 20# N-80 - 4.778" 10,246' 10,902' G1 G2 H1 7-5/8" H2/3 H4/5 H6 H8 H8 H8 H8 H10 `- 5-1/2" PBTD = 4,688' MD; 4,687' TVD TD=10,904' MD; 10,783' TVD MAX HOLE ANGLE = 17 deg No. Depth Length ID OD Item 1 19.5' 0.66 2.441 Tubing Hanger 2 4,698' Composite Plug w/10' cement @ 4,688' 30-25-18 PERFORATION HISTORY (DIL) Zone Top(MD) Us�20„yw�TUBING Top(TVD) Btm(TVD) Amt spf lot Date GI 10,374' 10,384' 10,267' 10,277' 30' 6 2" PJ HC, 60 deg DETAIL G2 10,407' 10,435' 10,145' 10,173' 10-3/4" 1 2-7/8" 6.5# L-80 EUE 8RD 2.441" Surface 1 2,002' 10,442' 10,448 10,333' 10,339' 6' 6 3-3/8" HC 60 deg 2/27/13 H1 2 A(„r/� i Fish Details: 19 Its of dropped 2-7/8" tubing (expected corkscrewed), seat nipple, 10,451' � f�`rJi Liner Top tubing anchor, desandor/degasser, mud joints and unloader valve. 6 2" PJ HC, 60 deg q ql 10,246' 10,467' 10,515' 10,357' 10,404' 48' 6 2" PJ HC, 60 deg JEWELRY DETAIL H2/3 10,469' G1 G2 H1 7-5/8" H2/3 H4/5 H6 H8 H8 H8 H8 H10 `- 5-1/2" PBTD = 4,688' MD; 4,687' TVD TD=10,904' MD; 10,783' TVD MAX HOLE ANGLE = 17 deg No. Depth Length ID OD Item 1 19.5' 0.66 2.441 Tubing Hanger 2 4,698' Composite Plug w/10' cement @ 4,688' 30-25-18 PERFORATION HISTORY (DIL) Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt spf Comments Date GI 10,374' 10,384' 10,267' 10,277' 30' 6 2" PJ HC, 60 deg 4/5/2001 G2 10,407' 10,435' 10,145' 10,173' 28' 6 2-7/8" HC, 60 deg 5/14/18 H1 10,442' 10,448 10,333' 10,339' 6' 6 3-3/8" HC 60 deg 2/27/13 H1 10,445' 10,451' 10,336' 10,342' 6' 6 2" PJ HC, 60 deg 4/5/2001 H2/3 10,467' 10,515' 10,357' 10,404' 48' 6 2" PJ HC, 60 deg 4/5/2001 H2/3 10,469' 10,514' 10,359' 10,403' 45' 6 3-3/8" HC 60 deg 2/27/13 H4/5 10,532' 10,580' 10,420' 10,467' 48' 6 3-3/8" HC 60 deg 2/27/13 H5 10,534' 10,565' 10,422' 10,452' 31' 6 1-11/16" HC 11/5/1999 10,565' 10,580' 10,452' 10,467' 15' 4 1-11/16" HC 2/23/1998 H6 10,596' 10,610' 10,482' 10,496' 14' 4 2-1/8" Enerjet 6/8/1995 H8 10,616' 10,634' 10,502' 10,519' 18' 4 2-18/" DA Slimkone 5/10/1983 6 3-3/8" Baker TCG 8/4/1986 H8 10,664' 10,672' 10,549' 10,556' 8' 4 2-18/" DA Slimkone 5/10/1983 6 3-3/8" Baker TCG 8/4/1986 H8 10,695' 10,703' 10,579' 10,587' 8' 4 2-18/" DA Slimkone 5/10/1983 4 3-3/8" Baker TCG 8/4/1986 H8 10,706' 10,710' 10,590' 10,593' 4' 42-18/" DA Slimkone 5/10/1983 6 3-3/8,' Baker TCG B 8/4/1986 H10 10,726' 10,732" 10,609' 10,615' 6' 4 2-18/" DA Slimkone 10/7/1982 6 3-3/8" Baker TCG 8/4/1986 NOTE: The Surface Casing annulus was used to dawn squeeze the liner lap during the 1986 workover of this well. Updated by DMA 11-16-18 THE STATE °fALASKA GOVERNOR BILL WALKER Chad Helgeson Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Swanson River Field, Hemlock Oil Pool, SCU 31-08 Permit to Drill Number: 181-099 Sundry Number: 318-440 Dear Mr. Helgeson: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.00gcc.alaska.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. DATED this S��day of October, 2018. Sincerely, Cath Commissioner RgDM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS .Y 20 AAC 25.280 OCT 0 1 201 f"9-OGCC 1. Type of Request: Abandon❑ Plug Perforation: Fracture Stimulate EIRepair Well El Operations shutdown ❑ Suspend � f Perforate ElOther Stimulate 11 Pull Tubing 0 Change Approved Program 1-1Plug for Redrill ❑ / Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: Set Plug/Run Kill Strinc Q 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Hilcorp Alaska, LLC Exploratory ❑ Development D - Stratigraphic ❑ Service ❑ 181-099 3. Address: 3800 Centerpoint Dr, Suite 1400 6. API Number: Anchorage Alaska 99503 50-133-20344-00-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A No Will planned perforations require a spacing exception? Yes El No Soldotna Creek Unit (SCU) 31-08 9. Property Designation (Lease Number): 10. Field/Pool(s): FEDA028997 Swanson River Field / Hemlock Oil ' it. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 10,904' 10,783' 4,719' 4,718' 662 psi NIA 4,719 8 10,613' Casing Length Size MD TVD Burst Collapse Structural Conductor 72' 20" 72' 72• Surface 3,354' 10-3/4" 3,354' 3,354' 3,130 psi 1,580 psi Intermediate Production 10,452' 7-5/8" 10,452' 10,343' 6,020 psi 3,400 psi Liner 656' 5-1/2" 10,902' 10,781' 9,190 psi 8,830 psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attached Schematic See Attached Schematic 2-7/8" 6.5# / L-80 4,278 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): N/A N/A 12. Attachments: Proposal Summary Q Wellbore schematic Q 13, Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch Q Exploratory ❑ Stratigraphic ❑ Development Q Service ❑ 14. Estimated Date for 15. Well Status after proposed work: CommencingOperations: October 12, 2018 P OIL WIND WDSPL LYS ❑ ❑ 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: Chad Helgeson 777-8405 Contact Name: Ted Kramer Authorized Title: Operations Manager Contact Email: tkramer@hilcom com Contact Phone: 777-8420 Authorized Signature:4��Vll Date: COMMI§SION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 31^XU _ q L4Q Plug Integrity BOP Test E]Mechanical Integrity Test E]n Location Clearance ACJ ,f '❑ 1 Other: iE A I+. P p la C.P-r+.�.>% `L�,rJ /C eaY �1 Z•6 AAA }E SI� ,� Jfl_rX.�l-. Y`GS w�•-�,.Q L'-' � r• ill Post Initial Injection MIT Req'd? Yes No D / `f 0 7 'to� Spacing Exception Required? Yes ❑ No 0 Subsequent Form Required:©- �/ ,� CT O 9 RBDMS %ACT J �n� APPROVED BY Approved by: \ V Y OMMISSIONER THE COMMISSION Date: to (!> It i� 3 / v} R P L ,g,�� /� ubm Form and /g Form 10403 Revised 4/2017 Approved ap rc t i I' r h from the date of approve. Attachments in Duplicate Z U Hil ora Alaska, LU Well Prognosis Well: SCU 31-08 Date: 9/26/2018 Well Name: SCU 31-08 API Number: 50-133-20344-00 Current Status: Rod Pump Oil Well Leg: N/A Estimated Start Date: October 12, 2018 Rig: 401 Reg. Approval Req'd? 403 Date Reg. Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 181-099 First Call Engineer: Ted Kramer (907) 777-8420 (0) (985) 867-0665 (M) Second Call Engineer: Chad Helgeson (907) 777-8405 (0) (907) 229-4824 (M) AFE Number: Current Bottom Hole Pressure: 1,690 psi @ 10,281' MD (Based on BHP gauges on 3/27/2016) Max. Potential Surface Pressure: 662 psi (Based on 0.1 gas gradient to surface) Brief Well Summary Soldotna Creek 31-8 was drilled in 1982 to target H8 and H10 oil reserves in the lower part of the Hemlock formation. Initial production from the H8 and H10 sands exceeded 1100 BOPD. Rapid production decline was attributed to asphaltene and/or paraffin deposits that increased in the wellbore as the GOR increased. These deposits were successfully treated with regular xylene stimulations. In 1986, a rig workover was conducted to replace the production packer and restore casing integrity by squeezing the liner lap. A new gas lift completion was run in 1989 to address a leaking packer and tubing. The upper part of the Hemlock formation (H1-4 sands) and the Tyonek G -Zone were perforated through tubing in 2001. The well went off production in 2002 with a suboptimal gas lift design unable to lift fluid to surface. The well was converted to Rotaflex Rod Pump in February 2013. In June 2014, the W, 7/8", and 1" rod string was replaced. In September 2016, the well stopped producing due to a deep rod part which was repaired in October 2016. _- September 2017 a %" rod part was repaired. The pump in this well locked up on startup after this rod repair. The well was rigged back up on in December 2017 but attempts to fish the broken rod were unsuccessful. Next, an attempt was made to pull the tubing but during this operation, the tubing string was dropped in the well. An attempt to fish the tubing string was also unsuccessful. The purpose of this work/sundry is to pull the Kill string and run a plug on top of the fish to isolate the perforations in the well. A kill string will then be re -ran in the well. Workover Ria Procedure: 1. Blow -down any pressure on the well. 2. MIRU 401 WO Rig. 3. ND Wellhead, NU BOP stack and test 250 psi Low/ 3,000 psi High, annular to 250 psi Low/ 2,500 psi High (hold each ram/valve and test for 5 -min). Record accumulator pre -charge pressures and chart tests. a. Perform Test. b. Notify AOGCC and BLM 24 hrs in advance of BOP test. c. Test VBR rams on 2-7/8" test joint. K Hi1wra Alaska, M d. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. Well Prognosis Well: SCU 31-08 Date: 9/26/2018 4. Unseat tubing anchor and pullout of hole with 2-7/8" kill string. Rack back 2,000 ft for a kill string and lay the rest down. E -line Procedure: 5. MIRU E -line, PT Lubricator to 2,500 psi Hi 250 Low. 6. PU RIH W/ a composite bridge plug / retainer. Set same at 4,700'. Place 10' of Cement on top. (Note: The 10' of cement is to protect the plug only. This plug is to set up the well so that the perfs are isolated now for TA status, but also so that the plug can be drilled out at a later date when the well is side tracked.) 7. RIH with 2,000' +/- kill string. 8. Pressure test casing to 1,500 psi. on chart for 30 minutes. •=—� 9. Install dry hole tree. P Ipv 10. RD #401 WO Rig. S t3 Attachments: 1. Schematic 2. Proposed Schematic 3. Well Head Diagram—Current 4. Well head diagram -Proposed 5. BOPE Diagram 6. Rig Flow/Circulating Diagram 7. RWO Change Form see_ vk Soldotna Creek Unit Well SCU 31Ran: 2/27/2013 SCHEMATIC PTD: 11-099 nilaoro Alveka. LLC API: 50-133-20344-00 CASING DETAIL Tag Fill Sand & 5/ RKB= 19.50'/ GL = 128'AMS PBTD = 4,719' MD; 4,718' TVD TD =10,904' MD; 10,783' TVD MAX HOLE ANGLE = 17 deg Size wt Grade Conn ID Top Btm 20" 94# H-40 - 19.124" Surface 72' 10-3/4" 40.5# K-55 - 10.050" Surface 3,354' 7-5/8" 33.7# S-95 - 6.765" Surface 28' 7-5/8" 26.4# N-80 - 6.969" 10,442' 10,448 7-5/8" 29.7# N-80 - 6.875" 3-3/8" HC 60 deg 10,452' 5-1/2" 20# N-80 - 4.778" 10,246' 10,902' TUBING DETAIL '3/4" 2-7/8" 6.5# L-80 I EUE8RD 2.441" Surface 1 4,278' F4 ' 719' -4-8 No. Fish Details: 19 its of dropped 2-7/8" tubing (expected corkscrewed), seat nipple, tubing anchor, desandor/degasser, mud joints and unloader valve. 0.66 1 2.441 PERFORATION HISTORY (DIL) Zone Top(MD) Btm(MD) Top(TVD) BLm(TVD) Amt spf Comments Date G3 10,374' 10,384' 10,267' 10,277' 10' 6 2" PJ HC, 60 deg 4/5/2001 G2 10,407' 10,435' 10,145' 10,173' 28' 6 2-7/8" HC, 60 deg 5/14/18 H1 10,442' 10,448 10,333' 10,339' 6' 6 3-3/8" HC 60 deg 2/27/13 HS 10,445' 10,451' 10,336' 10,342' 6' 6 2" P1 HC, 60 deg 4/5/2001 1-12/3 10,467' 10,515' 10,357' 10,404' 48' 6 2" PJ HC, 60 deg 4/5/2001 H2/3 10,469' 10,514' 10,359' 10,403' 45' 6 3-3/8" HC 60 deg 2/27/13 1-14/5 10,532' 10,580' 10,420' 10,467' 48' 6 3-3/8" HC 60 deg 2/27/13 HS 10,534' 10,565' 10,422' 10,452' 31' 6 1-11/16" HC 11/5/1999 10,565' 10,580' 10,452' 10,467' 15' 4 1-11/16- HC 2/23/1998 H6 10,596' 10,610' 10,482' 10,496' 14' 4 2-1/8" Enerjet 6/8/1995 H8 10,616' 10,634' 10,502' 10,519' 18' 4 2-18/"DA Slimkone 5/10/1983 6 3-3/8" Baker TCG 8/4/1986 H8 10,664' 10,672' 10,549' 10,556' 8' 4 2-18/"DA Slimkone 5/10/1983 6 3-3/8" Baker TCG 8/4/1986 H8 10,695' 10,703' 10,579' 10,587' 8' 4 2-18/" DA Slimkone 5/10/1983 4 3-3/8" Baker TCG 8/4/1986 H8 10,706' 10,710' 10,590' 10,593' 4' 4 2-18/" DA Slimkone 5/10/1983 63-3/8" Baker TCG 8/4/1986 H10 10,726' 10,732' 10,609' 10,615' 6' 4 2 -18/"DA Slimkone 10/7/1982 6 1 3-3/8" Baker TCG 8/4/1986 NOTE: The Surface Casing annulus was used to down squeeze the liner lap during the 1986 workover of this well. Updated by JLL 09/28/18 Soldotna Creek Unit Well SCU 31-05 PROPOSED PTD: Completion81-099 n: 2/27/2013 Hileoro Abe4e. LLf. API: 50-133-20344-00 RKB= 19.50'/ GL = 128'AMS y Lam'' TOF 4,719' 6-4-18 Tag Fill @ 10,613' Sand & Perf Debris 5/14/18 20" CASING DETAIL Size Wt Grade Conn ID Top Btm 20" 94# H-40 - 19.124" Surface 72' 10-3/4" 40.5# K-55 - 10.050" Surface 3,354' 7-5/8" 33.7# S-95 - 6.765" Surface 28' 7-5/8" 26.4# N-80 - 6.969" 10,442' 10,448 7-5/8" 29.7# N-80 - 6.875" 3-3/8" HC 60 deg 10,452' 5-1/2" 20# N-80 4.778" 10,246' 10,902' TUBING DETAIL 10-3/4" 1 2-7/8" 6.5# L-80 I E1JE8RD 2.441" Surface I ±2,000' 2 4 - Liner Top 10,246' = G1 G2 H1 7-5/8" 112/3 H4/5 H6 H8 H8 H8 H8 H10 5-1/2" PBTD = 4,719' MD; 4,718' TVD TD = 10,904' MD; 10,783' TVD MAX HOLE ANGLE =17 deg Fish Details: 19 jts of dropped 2-7/8" tubing (expected corkscrewed), seat nipple, tubing anchor, desandor/degasser, mud joints and unloader valve. JEWELRY DETAIL No. Depth Length ID OD Item 1 19.5' 0.66 2.441 Tubing Hanger 2 ±4,700' Composite Plug PERFORATION HISTORY (DIL) Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt spf Comments Date G1 10,374' 10,384' 10,267' 10,277' 10' 6 2" PJ HC, 60 deg 4/5/2001 G2 10,407' 10,435' 10,145' 10,173' 28' 6 2-7/8" HC, 60 deg 5/14/18 H1 10,442' 10,448 10,333' 10,339' 6' 6 3-3/8" HC 60 deg 2/27/13 HS 10,445' 10,451' 10,336' 10,342' 6' 6 2" P1 HC, 60 deg 4/5/2001 H2/3 10,467' 10,515' 10,357' 10,404' 48' 6 2" PJ HC, 60 deg 4/5/2001 H2/3 10,469' 10,514' 10,359' 10,403' 45' 6 3-3/8" HC 60 deg 2/27/13 H4/5 10,532' 10,584 10,420' 10,467' 48' 6 3-3/8" HC 60 deg 2/27/13 H5 10,534' 10,565' 10,422' 10,452' 31' 6 1-11/16" HC 11/5/1999 10,565' 10,580' 10,452' 10,467' 15' 4 1 1-11/16" HC 2/23/1998 H6 10,596' 10,610' 10,482' 10,496' 14' 4 2-1/8" Enerjet 6/8/1995 H8 10,616' 10,634 10,502' 10,519' 18' 4 2-18/"DASlimkone 5/10/1983 6 3-3/8" Baker TCG 8/4/1986 H8 10,664' 10,672' 10,549' 10,556' 8' 4 2-18/"DASlimkone 5/10/1983 6 3-3/8" Baker TCG 8/4/1986 H8 10,695' 10,703' 10,579' 10,587' 8' 4 2-18/" DASlimkone 5/10/1983 4 3-3/8" Baker TCG 8/4/1986 H8 10,706' 10,710' 10,590' 10,593' 4' 4 2-18/"DASlimkone 5/10/1983 6 3-3/8" Baker TCG 8/4/1986 H10 10,726' 10,732' 10,609' 10,615' 6' 4 2-18/" DA Slimkone 10/7/1982 6 3-3/8" Baker TCG 8/4/1986 NOTE: The Surface Casing annulus was used to down squeeze the liner lap during the 1986 workover of this well. Updated by 1LL 09/28/18 H Hilwrp Alagky LU: Swanson River SCU 31-08 10W X75/8 -X2718 Va live, wing,' SM FE, H1 Tubing head, FMC -TC, 115M X 71/165M, w/ 2- 21/16 SM 550, BG bottom prep Casing head, Gray, 1151% 10 %SOW, w/ 2-2" LPI Swanson River SCU 31-08 09/26/2018 Tubing bangeq Seaboard, ECO tension, 71/16 SM X 2 7/e EUE lift and cusp, w/ 2 type H BPV, 8/8 control line, 5" siickneck, eft to release, right t0 engage Full stainless steel for Chemical inja ion Special Cross, 2 9/165M FE X 27/8 EUE 8rd w/ 2-21/16 5M 550 M, 21/16 D trim H Hildvp M.A., IAA: Casingl 10 %! Swanson River SCU 31-08 Proposed 09/26/2018 Swanson River Tubing hanger. CW-C-EN- SCU 31-08 CCL, 7 X 2 7/8 EUE Bid lift IO Y."X75/8"X27/6 and 27/8 EUE susp, w/ 21/2" type H BPV profile, 5 Y EN, Alloy material HILCORP ALASKA 7-1/16" 5M BOPE 7-1/16" 5M HYDRIL GK ANNULAR 32" TALL, FLANGE TO FLANGE 5M LWS DBL GATE BOP DRESSED W/VARIABLE RAMS IN TOP DRESSED W/BLIND RAMS IN BOTTOM 26-3/4" TALL, FLANGE TO FLANGE 7-1/16" 5M DRILLING SPOOL W/2-1/16" 5M OUTLETS 18" TALL, FLANGE TO FLANGE ^77" TOTAL STACK HEIGHT ANNULAR STYLE BOP SPECS: - 3.30 gallon open chamber volume - 3.86 gallon close chamber volume GATE STYLE BOP SPECS: -1.45 gallons to close per gate -1.18 gallons to open per gate - 5.45:1 closing ratio -1.93:1 opening ratio HHilcorp Alaska, LLC Hilcorp Alaska, LLC Changes to Approved Rig Work Over Sundry Procedure Subject: Changes to Approved Sundry Procedure for Well SCU 31-08 (PTD 181-099) Sundry #: XXX -XXX Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to the AOGCC by the rig workover (RWO) "first call' engineer. AOGCC written approval of the change is required before implementing the change. Sec Page Date Procedure Change New 403 Required? Y / N HAK Prepared By Initials HAK AOGCC Written Approved Approval Received By (Person and Date) Initials Approval: Prepared: Asset Team Operations Manager Date First Call Operations Engineer Date Schwartz, Guy L (DOA) From: Ted Kramer <tkramer@hilcorp.com> Sent: Wednesday, October 03, 2018 9:38 AM To: Schwartz, Guy L (DOA) Cc: Donna Ambruz Subject: SCU 31-08, PTD#- 181-099, Suspend Well Guy, As per our phone conversation today, the SCU 31-8 well was an oil producer making 10 BOPD via Rod Pump. While pulling tubing, the tubing was dropped in the well resulting with a corkscrewed fish that we were not able to easily fish. Hilcorp desires to suspend the well for now because while the well is not fishable for 10 BOPD, but, it is in a good location to side track to a better bottom hole location. Therefore, we would like to suspend now, place a composite (drillable) bridge plug with minimum cement (10') to set the well up to come back later, mill and fish for a sidetrack. Ted Kramer Sr. Operations Engineer Hilcorp Alaska, LLC. O 907-777-8420 C 985-867-0665 HILCORP ALASKA LLC, SOLDOTNA CK UNIT 31-08 (181-099) SWANSON RIVER, HEMLOCK OIL Monthly Production Rates 10,000,000 10,000,000 Cum. Prod Oil (bbls): 897,681 Cum. Prod Water (bbls): 186,086 Cum. Prod Gas (mcF): 35,717,941 ITT ---------. W 1,000,000 1,000,000 Y O .. __. _. _.._. ♦i _� _..._ M f O e e 100,000 100,000 • u° v — --.— 0 LL 4 'fib° A°- .t ec ��_. 0 �d O Na 10,00010000 S cc 4! C7 0 0 I - - e a °� ° W Y O O H it O mei ♦ d O e o a d i 1,000 1,000 8 V O4 4 O O 0° — 0 008 8. 000 CI (D Att rOv 100 -- ° °''�°�oe-- .� — 100 _. °.. O ° K 10 -- _-- — — 10 s —e Produced Gas (MCFM) IT GOR ° Produced Water (BOPM) -o— Produced Oil (BOPM) 1 1 Jan -1980 Jan -1985 Jan -1990 Jan -1995 Jan -2000 Jan -2005 Jan -2010 Jan -2015 Jan -2020 SPREADSHEET -Prod -inject CuNes_W ell_V 116_1810990_SCU_31-08_20181002.xlsx 10/2/2018 • • _ STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION Reviewed By:� -Si P.I.Supry �I BOPE Test Report for: SOLDOTNA CK UNIT 31-08 Comm Contractor/Rig No.: Moncla 401 PTD#: 1810990 - DATE: 5/10/2018 - Inspector Adam Earl t Insp Source; Operator: HILCORP ALASKA LLC Operator Rep: C.Bartlewski Rig Rep: Gamaliel Salas Inspector Type Operation: WRKOV Sundry No: Test Pressures: Inspection No: bopAGE180513095917 Rams: Annular: Valves: MASP: Type Test: INIT 318-178 } 250/3000 ' 250/2500' 250/3000 - 662 ,, , Related Insp No: TEST DATA MISC. INSPECTIONS: f MUD SYSTEM: ACCUMULATOR SYSTEM: P/F Visual Alarm Time/Pressure P/F Location Gen.: P Trip Tank P , NA System Pressure 3000 - P !' Housekeeping: P - Pit Level Indicators NA NA 'Pressure After Closure 2450 - P - ' PTD On Location P - Flow Indicator NANA - 200 PSI Attained 30 - P - Standing Order Posted P Meth Gas Detector PP _ r Full Pressure Attained _ 91 _ P _ Well Sign P1 H2S Gas Detector P - P - Blind Switch Covers: all stations -P - _ Drl. Rig P _ MS Misc 0 NA 1 Nitgn.Bottles(avg): 6*2000 - P '- Hazard Hazard Sec. P ACC Misc 0 NA Misc NA ' FLOOR SAFTY VALVES: BOP STACK: CHOKE MANIFOLD: Quantity P/F Quantity Size P/F Quantity P/F €' Upper Kelly 0 NA Stripper 0 _- NA No.Valves 8 - P Lower Kelly 0 NA Annular Preventer . 1 - 7" __ _ P ' Manual Chokes 2 - P Ball Type 0 NA #1 Rams 1 _2 3/8x 3 1/2 _ P - Hydraulic Chokes 0 _ NA Inside BOP 1 - P #2 Rams 1 - Blind _ P CH Misc 0 NA FSV Misc 0 NA #3 Rams 0 NA #4 Rams 0 #5 Rams 0 NA INSIDE REEL VALVES: #6 Rams __0 NA (Valid for Coil Rigs Only) Choke Ln.Valves 1 - 2" - _ P - Quantity P/F HCR Valves 1 2" P " Inside Reel Valves 0 NA Kill Line Valves 2 - 2" P Check Valve 0 NA BOP Misc 0 NA j j 1 Number of Failures: 0 ✓ Test Results Test Time 3 Remarks: 5 tests, Only one test jt.-2 7/8" SCANNED JUN 0 42•018 Py OF Ttj� 41, THE STATE Alaska Oil and Gas F.4;09611%,,70. 4of® T 1 T e Conservati®n Commission " r - _ 333 West Seventh Avenue � Anchorage, Alaska 99501-3572 � GOVERNOR BILL WALKER g OF Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Chad Helgeson Operations ManagerSCANNED Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Swanson River Field, Hemlock Oil Pool, SCU 31-08 Permit to Drill Number: 181-099 Sundry Number: 318-178 Dear Mr. Helgeson: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Hollis S. French Chair DATED this day of April, 2018. RBDMS___� APR302019 • 0 RECEIVED STATE OF ALASKA APR2 4 2°18 ALASKA OIL AND GAS CONSERVATION COMMISSION 1 APPLICATION FOR SUNDRY APPROVALS U 6 GUC 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Repair Well Q . Operations shutdown❑ Suspend ❑ Perforate 0 • Other Stimulate ❑ Pull Tubing 2 . Change Approved Program El Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other:Recovery/Replace Rod Pump❑✓ • 2.Operator Name: 4.Current Well Class: 5. Permit to Drill Number: Hilcorp Alaska,LLC Exploratory ❑ Development Q • 181-099 • 3.Address: 3800 Centerpoint Dr,Suite 1400 Stratigraphic ❑ Service ❑ 6.API Number: Anchorage Alaska 99503 50-133-20344-00 - 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? CO 123A Soldotna Creek Unit(SCU)31-08 Will planned perforations require a spacing exception? Yes ❑ No 9.Property Designation(Lease Number): 10. Field/Pool(s): FEDA028997 - Swanson River Field/Hemlock Oil • 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): 10,904' ., 10,783' 10,854' 10,734' 662 psi N/A 10,627'(fill) Casing Length Size MD TVD Burst Collapse Structural Conductor 40' 20" 72' 72' Surface 3,354' 10-3/4" 3,354' 3,354' 3,130 psi 1,580 psi Intermediate Production 10,452' 7-5/8" 10,452' 10,343' 6,020 psi 3,400 psi Liner 656' 5-1/2" 10,902' 10,781' 9,190 psi 8,830 psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic See Attached Schematic 2-718" 6.5#/L-80 10,417' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): Anchor; N/A 10,421'MD/10,313'TVD; N/A 12.Attachments: Proposal Summary Q Wellbore schematic 0 113.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch Q Exploratory ❑ Stratigraphic ❑ Development Q• Service 0 14. Estimated Date for 15.Well Status after proposed work: May 8,2018 Commencing Operations: OIL 2 • WINJ ❑ WDSPL 0 Suspended 0 16.Verbal Approval: Date: GAS 0 WAG ❑ GSTOR 0 SPLUG 0 Commission Representative: GINJ 0 Op Shutdown 0 Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Chad Helgeson 777-8405 Contact Name: Ted Kramer Authorized Title: Operations Manager Contact Email: tkramert hilcorp.com J / Contact Phone: 777-8420 Authorized Signature: / Date: 411Z///7 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: f✓, 1 n 1 Q,p_ In Plug Integrity 0 BOP Test Mechanical Integrity Test ❑ Location Clearance 0 Other: .i�_ 3l✓G O�S L x F Post Initial Injection MIT Req'd? Yes ❑ No El Spacing Exception Required? Yes ❑ No p Subsequent Form Required: r0 -- 4/01 t APPROVED BY Approved by s��L COMMISSIONER THE COMMISSION Date: ( iI�a e( ALi-24/-15 S� Af�i�3K-fl .z s. e (`� ` S 2 1mit Form and 1,4 Form 10-403 Revised 4/2017 Appr•��d appli ti nRlid fpr fN A t�the BD�I d4A1'� AtFa�FS in Duplicate i • Well Prognosis Well: SCU 31-08 Hilcorp Alaska,LL Date:4/23/2018 Well Name: SCU 31-08 API Number: 50-133-20344-00 Current Status: Rod Pump Oil Well Leg: N/A Estimated Start Date: May 8, 2018 Rig: Moncla 401 Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 181-099 First Call Engineer: Ted Kramer (907) 777-8420(0) (985) 867-0665 (M) Second Call Engineer: Chad Helgeson (907) 777-8405 (0) (907) 229-4824 (M) AFE Number: Current Bottom Hole Pressure: 1,690 psi @ 10,281' MD (Based on BHP gauges on 3/27/2016) Max. Potential Surface Pressure: 662 psi (Based on 0.1 gas gradient to surface) Brief Well Summary Soldotna Creek 31-8 was drilled in 1982 to target H8 and H10 oil reserves in the lower part of the Hemlock formation. Initial production from the H8 and H10 sands exceeded 1100 BOPD. Rapid production decline was attributed to asphaltene and/or paraffin deposits that increased in the wellbore as the GOR increased. These deposits were successfully treated with regular xylene stimulations. In 1986, a rig workover was conducted to replace the production packer and restore casing integrity by squeezing the liner lap. A new gas lift completion was run in 1989 to address a leaking packer and tubing. The upper part of the Hemlock formation (H1-4 sands) and the Tyonek G-Zone were perforated through tubing in 2001. The well went off production in 2002 with a suboptimal gas lift design unable to lift fluid to surface. The well was converted to Rotaflex Rod Pump in February 2013. In June 2014,the%", 7/8",and 1" rod string was replaced. In September 2016,the well stopped producing due to a deep rod part which was repaired in October 2016. September 2017 a %" rod part was repaired. The pump in this well locked up on startup after this rod repair. The well was rigged back up on in December 2017 but attempts to fish the broken rod were unsuccessful. The purpose of this work/sundry is to pull the tubing to recover stuck pump and broken rods. Perforate the G- 2 rerun the tubing and rod string and place the well back on production. Notes Regarding Wellbore Condition • Well is currently not producing on rod pump (suspected stuck pump). Pre-Sundry Work • Rig up Slickline and pick up tubing punch. RIH to top of parted rods and punch a hole to drain fluid to avoid pulling a wet tubing string. RD Slickline. Workover Rig Procedure: (This work is a continuation from Sundry#317-567) 1. Blow-down any pressure on the well and shoot fluid level (echometer)on casing. 2. Roll back Rotoflex pumping unit, uncouple and LOTO motor. i • Well Prognosis Well: SCU 31-08 Hilcorp Alaska,LI) Date:4/23/2018 3. MIRU Moncla #401 WO Rig. 4. ND Well head, NU BOP stack and test 250 psi Low/3,000 psi High annular to 250 psi Low/2,500 psi High (hold each ram/valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. a. Perform Test. gay b. Notify AOGCC and BLM 24 hrs in advance of BOP test. c. TestR rVl1am o 2-7/8" test joint. d. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 5. Unseat tubing anchor and pull out of hole with 2-7/8"tubing, racking back in derrick. Note: Visually inspect tubing as it is coming out of the well. 6. Lay down tubing anchor, send in pump to be removed from landing nipple. E-line Procedure: 7. MIRU E-line, PT Lubricator to 2,500 psi Hi 250 Low. 8. RU HC wireline guns. 9. RIH and perforate the following interval: Zone Sands Top (MD) Btm (MD) FT Tyonek G-2 10,407' 10,435' 28 a. Proposed perfs shown on the proposed schematic in red font. b. Final Perfs tie-in sheet will be provided in the field for exact perf interval. c. Correlate using proposed Gamma/CCL. 10. POOH. RD E-line. 11. PU mud anchor Seat nipple and tubing anchor. RIH on 2-7/8"tubing. 12. Set Tubing anchor and land tubing hanger. 13. Pump 20 bbls of diesel to flush pipe. 14. PU and inspect existing dip tube. 15. PU new 1-3/4" rod pump. 16. RIH with rod string (sinker bars, 3/4", 7/8" and 1"). (Note: Rods will be replaced as needed). 17. Space out the rods, install_polish rod. 18. Test pump to 700 psig for 5 minutes to confirm seated in profile 19. ND rod stripper, install surface equipment onto well and test to 1,500 psi. 20. RD Moncla#401 WO Rig. 21. Roll up Rotoflex pumping unit, recouple, and remove LOTO on motor. 22. Return to production with same surface safety system as previously ins.9_1Ied. 23. Replace IA x OA pressure gauge if removed (7-5/8" x 10-3/4"). Attachments: 1. Schematic 2. Proposed Schematic 3. Well Head Diagram—Current/Proposed (Same) 4. BOPE Diagram 5. Rig Flow/Circulating Diagram 6. RWO Change Form Soldotna Creek Unit Et 0 • Well SCU 31-08 SCHEMATICCompletion 181 099 n:2/27/2013 PTD Hileoro Alaska,LLC API: 50-133-20344-00 CASING DETAIL RKB= 19.50'/GL=128'AMSL Size Wt Grade Conn ID Top Btm A 11 20" 94# H-40 - 19.124" Surface 72' 10-3/4" 40.5# K-55 10.050" Surface 3,354' 7-5/8" 33.7# S-95 - 6.765" Surface 7-5/8" 26.4# N-80 - 6.969" B -- 2 01 7-5/8" 29.7# N-80 - 6.875" 10,452' 5-1/2" 20# N-80 - 4.778" 10,246' 10,902'___ TUBING DETAIL 2 2-7/8" 6.5# L-80 EUE 8RD 2.441" Surface 10,417' I 10-3/4" a 8 8 Liner Top JEWELRY DETAIL C 10,246' No. Depth Length ID OD Item 1 19.5' 0.66 2.441 Tubing Hanger 2 2,501' 2.32 2.430 4.00 Chemical Injection Mandrel 3 10,417' 0.65 2.441 3.50 Seating Nipple D - — G1 4 10,418' 2.32 2.441 4.50 Tubing Anchor(Set 19k tension) 5 10,421' 0.35 2.992 3.50 Crossover XO 2-7/8"Box 8rd x3-1/2"Pin 8rd E 6 10,421' 4.00 2.992 3.50 Slotted Sub _ 7 10,425' 63.43 2.992 3.50 2 jts 3-1/2"Tubing -1 3 kV. r 8 10,489' 0.44 2.992 3.80 Bull Plug 4 4-° 5 Pe F 6 — H1 ROD DETAIL — L 7 7-5/8" No. Depth Length OD Item II 8 A 15' 40' 1-1/2" Polished Rod,30'in well H2/3 B 55' 450' 1" 1"x 25'EL Sucker rods w/ 3 XL guides per rod I 505' 2,825' 1" 1"x 25'EL Sucker rods w/"No"XL guides per rod 3,330' 3,550' 7/8" 7/8"x 25'EL Sucker rods w/ 3 XL guides per rod 6,880' 750' 3/4" 3/4"x 25'EL Sucker rods w/ 3 XL guides per rod — H4/5 7,630' 250' 3/4" 3/4"x 25'EL Sucker rods w/ 12 XL guides per rod 7,880' 2,175' 3/4" 3/4"x 25'EL Sucker rods w/ 3 XL guides per rod C 10,055' 300' 1-1/2" 1-1/2"x 25'K Bars(weight bars) Tag Fill @ 10,613' H6 D 10,355' 32.5' 1" 1"x 30"Stabilizer Bar w/"A"Pins Sand&Perf Debris E 10,388' 42' 1-3/4" 1-3/4"x 42'Insert Pump,RHBC Pump#5178 w/PA Ring 2/26/13 rti}}r';}}}tir"= H8 80 PA Ring,Sand Seal,2-1/2"x 1-3/4"x 36"x 36-1/2"x 37" 1•ti•ti•ti•ti• 'r.r.r.r.r.r• r:rrfr ftif RHBC(NEW 10/13/16) ';:r~r1r�r:r:i F 10,430' 16' 1-1/2" Dip Tube `•`:'`•:• � H8 '�•r•r•r•r•r• S•5.•L•5�•ti• '�•r•r•r•r•r ,f.rsertirrs ti.ti•1.ti•ti•ti•• •r•r•r•r•r•r•r ti•ti•L•ti•ti•5n` 'r•r•r•r•r•r•` H8 .rtirtirLrtir.r .rtirtirtirtirtir:r 'r•r•r•r•r•r•r 1.1.5•ti•ti• i.r•r.r•r•r — H8 ti•ti•1•ti•ti•ti+` .:1fj:ffbr r1r1:::::;rtir, r•r•r,r•r•r•r 1. '•�1r1L.•1rLrSr' ::rrrl..v. H10 'r�r1lrrl�Nid rrrr1 .:rtir1r:r:rM Pr~rtir:PP 1•S•1•ti•ti•'4I 'r•r•r.r•r•r•r Pr•r•r•r•r•r 1:r:rlrti P:. ti•S•1•L•ti•ti•' ":41:::1:'1545' PERFORATION DETAIL ON NEXT PAGE '�•rr•r•rrr •r1 f1f1r1f1r1f '1.5.5.5.5.5.5 1.1.1•L•1•ti•' 'S•r•r•5•r•r•r •..ti.1.1.1.1•' ;.'r•r•r•r'f'r' NU t:The Surface Casing annulus was used to down squeeze the 1.9,.1.1• .ti. r_; `: 0, 5-1/2" liner lap during the 1986 workover of this well. PBTD=10,854'MD;10,734'TVD TO=10,904'MD;10,783'ND MAX HOLE ANGLE=17 deg Downhole Revised:06/20/14 Updated by DMA 04-23-18 Soldotna Creek Unit • Well SCU 31-08 SCHEMATICCompletion 181 099 Ran:2/27/2013 PTD Hiles.Alaska.LLC API: 50-133-20344-00 PERFORATION HISTORY(DIL) Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt spf Comments Date G1 10,374' 10,384' 10,267' 10,277' 10' 6 2"PJ HC,60 deg 4/5/2001 H1 10,442' 10,448 10,333' 10,339' 6' 6 3-3/8"HC 60 deg 2/27/13 H1 10,445' 10,451' 10,336' 10,342' 6' 6 2"PJ HC,60 deg 4/5/2001 H2/3 10,467' 10,515' 10,357' 10,404' 48' 6 2"PJ HC,60 deg 4/5/2001 H2/3 10,469' 10,514' 10,359' 10,403' 45' 6 3-3/8"HC 60 deg 2/27/13 H4/5 10,532' 10,580' 10,420' 10,467' 48' 6 3-3/8"HC 60 deg 2/27/13 H5 10,534' 10,565' 10,422' 10,452' 31' 6 1-11/16"HC 11/5/1999 10,565' 10,580' 10,452' 10,467' 15' 4 1-11/16"HC 2/23/1998 H6 10,596' 10,610' 10,482' 10,496' 14' 4 2-1/8"Enerjet 6/8/1995 H8 10,616' 10,634' 10,502' 10,519' 18' 4 2-18/"DA Slimkone 5/10/1983 6 3-3/8"Baker TCG 8/4/1986 H8 10,664' 10,672' 10,549' 10,556' 8' 4 2-18/"DA Slimkone 5/10/1983 6 3-3/8"Baker TCG 8/4/1986 H8 10,695' 10,703' 10,579' 10,587' 8' 4 2-18/"DA Slimkone 5/10/1983 4 3-3/8"Baker TCG 8/4/1986 H8 10,706' 10,710' 10,590' 10,593' 4' 4 2-18/"DA Slimkone 5/10/1983 6 3-3/8"Baker TCG 8/4/1986 H10 10,726' 10,732' 10,609' 10,615' 6' 4 2-18/"DA Slimkone 10/7/1982 6 3-3/8"Baker TCG 8/4/1986 Downhole Revised:06/20/14 Updated by DMA 04-23-18 Soldotna Creek Unit H . Well SCU 31-08 P •O P O S E D SCHEMATIC Completion 181 099Ran:2/27/2013 PTD Hilcora Alaska,LLC API: 50-133-20344-00 CASING DETAIL RKB= 19.50'/GL=128'AMSL Size Wt Grade Conn ID Top Btm A * 11 20" 94# H-40 - 19.124" Surface 72' 10-3/4" 40.5# K-55 - 10.050" Surface 3,354' 7-5/8" 33.7# S-95 - 6.765" Surface 7-5/8" 26.4# N-80 - 6.969" B — 20" 7-5/8" 29.7# N-80 - 6.875" 10,452' 5-1/2" 20# N-80 - 4.778" 10,246' 10,902' TUBING DETAIL 2 2-7/8" 6.5# L-80 EUE 8RD 2.441" 1 Surface 10,417' 10-3/4" E Liner Top JEWELRY DETAIL C 10,246' No. Depth Length ID OD Item 1 19.5' 0.66 2.441 Tubing Hanger 2 2,501' 2.32 2.430 4.00 Chemical Injection Mandrel 3 10,417' 0.65 2.441 3.50 Seating Nipple D G1 4 10,418' 2.32 2.441 4.50 Tubing Anchor(Set 19k tension) 5 10,421' 0.35 2.992 3.50 Crossover XO 2-7/8"Box 8rd x3-1/2"Pin 8rd E i,� G2 6 10,421' 4.00 2.992 3.50 Slotted Sub � 7 10,425' 63.43 2.992 3.50 2 jts 3-1/2"Tubing 1 1 3 8 10,489' 0.44 2.992 3.80 Bull Plug 4 5 F i 6 H1z iROD DETAIL 7 7-5/8" No. Depth Length OD Item 8 A 15' 40' 1-1/2" Polished Rod,30'in well H2/3 B 55' 450' 1" 1"x 25'EL Sucker rods w/ 3 XL guides per rod 505' 2,825' 1" 1"x 25'EL Sucker rods w/"No"XL guides per rod 3,330' 3,550' 7/8" 7/8"x 25'EL Sucker rods w/ 3 XL guides per rod 6,880' 750' 3/4" 3/4"x 25'EL Sucker rods w/ 3 XL guides per rod H4/5 7,630' 250' 3/4" 3/4"x 25'EL Sucker rods w/ 12 XL guides per rod 7,880' 2,175' 3/4" 3/4"x 25'EL Sucker rods w/ 3 XL guides per rod H6 C 10,055' 300' 1-1/2" 1-1/2"x 25'K Bars(weight bars) Tag Fill @ 10,613' D _10,355' 32.5' 1" 1"x 30"Stabilizer Bar w/'A"Pins Sand&Perf Debris E 10,388' 42' 1-3/4" 1-3/4"x 42'Insert Pump,RHBC Pump#5178 w/PA Ring f•r•r•r•r•r'f H8 2/26/13 '} 80 PA Ring,Sand Seal,2-1/2"x 1-3/4"x 36"x 36-1/2"x 37" 1}1}y}y:1}y,� •e?fti?ffRHBC(NEW 10/13/16) •::::::::::::::::::::•'' 1.1.1.1.1.1•• F 10,430' 16' 1-1/2" Dip Tube r•rir{r{:{74*''S •r•r•r•r•r•r . .. r•r•r•r•r•r•r • ii:.:5ig•:}` H8 .1.1.1.1.1.1.• rtirtiltilti::;:% 'r•r•r•r•r•r•r 14:::::::::::::::::::. H8 •rtiflftiftiftif J' •r:PY::tirtirtir •f:f:f:f:j:f:f .1.1 1 .1. . 1•' ;•r•r•r• •r•r H8 5.•f;f;f;j;f;f;1 1.1.1.1.1.1•' •51r.1•r1r1r1r•r• r1rrr•r.r1• H10 1.1.1.1.1.1.• i•::?..F r•r.r 1.1.1.1.1.1.• t1r1r15v.s.tr• •r•rrr•r•rr .:::::::::PP.*:,.. 5:1. .1.1.1•' r rrr::::Y*• r•r•r•f•r•r•r 1.::1:1:*vc. •rir1r1r:ryr:r •r1.1.1.1.1.1•' •r•r•r•r•r•r 1.1.1.1.1.1.• ...7.1:::::::::::::4*1• rf11r•r•r•r•r•11.1••r PERFORATION DETAIL ON NEXT PAGE .fti f1 f::::P S f 1.1.:::J4' .f1 f1 f1SiSg f 1.1.1.1.1.1• NOTE:The Surface Casing annulus was used to down squeeze the I 0 ` j 5-1/2" liner lap during the 1986 workover of this well. PBTD=10,854'MD;10,734'TVD TD=10,904'MD;10,783'TVD MAX HOLE ANGLE=17 deg Downhole Revised:06/20/14 Updated by DMA 04-23-18 Soldotna Creek Unit Well P O P O S E D SCHEMATICSCU 31-08 Completion n:2/27/2013 PTD 181 099 ear ,u:,'ka,IAA, API: 50-133-20344-00 PERFORATION HISTORY(DIL) Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt spf Comments Date G1 10,374' 10,384' 10,267' 10,277' 10' 6 2"PJ HC,60 deg 4/5/2001 G2 10,407' 10,435' 10,145' 10,173' 28' 6 TBD Proposed • H1 10,442' 10,448 10,333' 10,339' 6' 6 3-3/8"HC 60 deg 2/27/13 H1 10,445' 10,451' 10,336' 10,342' 6' 6 2"PJ HC,60 deg 4/5/2001 H2/3 10,467' 10,515' 10,357' 10,404' 48' 6 2"PJ HC,60 deg 4/5/2001 H2/3 10,469' 10,514' 10,359' 10,403' 45' 6 3-3/8"HC 60 deg 2/27/13 H4/5 10,532' 10,580' 10,420' 10,467' 48' 6 3-3/8"HC 60 deg 2/27/13 H5 10,534' 10,565' 10,422' 10,452' 31' 6 1-11/16"HC 11/5/1999 10,565' 10,580' 10,452' 10,467' 15' 4 1-11/16"HC 2/23/1998 H6 10,596' 10,610' 10,482' 10,496' 14' 4 2-1/8"Enerjet 6/8/1995 H8 10,616' 10,634' 10,502' 10,519' 18' 4 2-18/"DA Slimkone 5/10/1983_ 6 3-3/8"Baker TCG 8/4/1986 H8 10,664' 10,672' 10,549' 10,556' 8' 4 2-18/"DA Slimkone 5/10/1983 6 3-3/8"Baker TCG 8/4/1986 H8 10,695' 10,703' 10,579' 10,587' 8' 4 2-18/"DA Slimkone 5/10/1983 4 3-3/8"Baker TCG 8/4/1986 H8 10,706' 10,710' 10,590' 10,593' 4' 4 2-18/"DA Slimkone 5/10/1983 6 3-3/8"Baker TCG 8/4/1986 H10 10,726' 10,732' 10,609' 10,615' 6' 4 2-18/"DA Slimkone 10/7/1982 6 3-3/8"Baker TCG 8/4/1986 Downhole Revised: 06/20/14 Updated by DMA 04-23-18 • • II Swanson River SCU 31-08 If h r,, 11:14,1.1.f.t. 02/16/2013 Swanson River Tubing hanger,Seaboard, SCU 31-08 ECO tension,7 1/16 5M X 2 10 1,"X 7 5/8"X 2 7/8 7/8 EUE lift and susp,w/2'/: type H BPV,3/8 control line, 5"slickneck,left to release, right to engage Full stainless steel for chemical injection Special Cross,2 9/16 5M FE X 2 7/8 EUE 8rd w/2-2 1/16 5M SSO Valve,wing,WKM-M,2 1/16 i / i Valve,wing,WKM-M,2 1/16 5M FE,HWO,DD trim ,. 1 SM FE,HWO,DD trim - 7 � 0 1:, ® -,fr ®moo)® ®(o ie 7 C ) Adapter,Seaboard,7 1/16 _■ SMFEX29/165Mw/5"PP Grade Level I■ lseal pocket,'A control line � exit,alloy material Tubing head,FMC-TC,11 5M X71/165M,w/2-21/3.6 ( - ��-�— l SM SSO,BG bottom prep - ll 1 ii II 47" . 7_, :u III n al : :-.: • . , Casing head,Gray,11 5M X 10'/,SOW,w/2-2"LPO I III ill NNW 1111 � 4/111-1.1 I 4C �® 1 , • HILCORP ALASKA 7-1/16" 5M BOPE ( 1 7-1/16" 5M HYDRIL GK ANNULAR 32"TALL, FLANGE TO FLANGE i 1 7-1/16" 5M LWS DBL GATE BOP DRESSED W/VARIABLE RAMS DRESSED W/BLIND RAMS IN BOTTOMINTOP (6)- 26-3/4"TALL, FLANGE TO FLANGE 7-1/16" 5M DRILLING SPOOL _14W/2-1/16" 5M OUTLETS 695efil n 18"TALL, FLANGE TO FLANGE 77"TOTAL STACK HEIGHT ANNULAR STYLE BOP SPECS: -3.30 gallon open chamber volume -3.86 gallon close chamber volume GATE STYLE BOP SPECS: - 1.45 gallons to close per gate - 1.18 gallons to open per gate -5.45:1 closing ratio - 1.93:1 opening ratio • 0 aw 2 x F,a �u 1. U W a-' • .o 2? a cai '- a.E. co co 66 0 0 O 0 kr Lx. o LL S' 0 c _ 0 o G ii 2 u. o az It Q l7 oc g o z z ° 0 o vw oa a0z -1 L.L. nil D? 2a . . • • 0a" c / > W7 0 a Q _ /E 002 U 2k ° § / O. E E c 0o 0 2 _> \ § = a '\ < \ \ � CD / -0 > �� k> s f \ {. Es § .% n o a) 3 \ � � � k k $ %a )>- a) / O � cc 0 i co Z CI \ 5 � a / § 0 CO / a Cl. el /k Cl) ca o \ 0 ■ L6k / / / «L. 2 < _C szu 0 E § / = = e O 2 § .E 2 L k / § \ ) to-, § .� 7 / 2 3 Cl) = CO c Lu \ ) > LI C P. ( — o a � 8 «C0 0 m a. .x o kco 6 E % / � � & x � f 0 ® a 2 k C \ e to 7 1 0 .c / Cori — 0 GG T k C \/ / 0 / I I \ \ I M 0 \ •OF tiT4 gw�\\(%% � THE STATE ^KA Alaska Oil and Gas of L Conservation Commission ,...t = 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 ®F ALASFax: 907.276.7542 www.aogcc.alaska.gov Chad Helgeson 184ED DEC, Gale Operations Manager `� Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Swanson River Field, Hemlock Oil Pool, Soldotna Creek Unit 31-08 Permit to Drill Number: 181-099 Sundry Number: 317-567 Dear Mr. Helgeson: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Hollis S. French Chair DATED this 3 day of December, 2017. ra7:173 r 27,.7 0 4111 RE STATE OF ALASKANOV 3 0 2017 ALASKA OIL AND GAS CONSERVATION COMMISSION p (2.17 /7 APPLICATION FOR SUNDRY APPROVALS AOGC 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Repair Well 0 ° Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing 0 Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: Replace Pump&Rods n 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. Hilcorp Alaska,LLC Exploratory ❑ Development 0. 181-099 ° 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic 0 Service ❑ 6.API Number. Anchorage,AK 99503 50-133-20344-00-00 ' 7. If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A Will planned perforations require a spacing exception? Yes ❑ No 0 Soldotna Creek Unit(SCU)31-08 ' 9.Property Designation(Lease Number): 10.Field/Pool(s): FEDA028997 Swanson River Field/Hemlock 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): 10,904 ' 10,783 ' 10,854 10,734 662 psi N/A 10,613(fill) Casing Length Size MD TVD Burst Collapse Structural Conductor 72' 20" 72' 72' Surface 3,354' 10-3/4" 3,354' 3,354' 3,130 psi 1,580 psi Intermediate Production 10,452' 7-5/8" 10,452' 10,343' 6,020 psi 3,400 psi Liner 656' 5-1/2" 10,902' 10,781' 9,190 psi 8,830 psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 10,374-10,732 10,267-10,615 2-7/8" 6.5#/L-80 10,417 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): Anchor&N/A 10,418(MD)10,310(TVD)&N/A 12.Attachments: Proposal Summary 0 Wellbore schematic El 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch 0 Exploratory ❑ Stratigraphic❑ Development 0 " Service ❑ 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 12/13/2017 OIL 0 ' WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR 0 SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Chad Helgeson Contact Name: Ted Kramer Authorized Title: Operations Manager Contact Email: tkramer -hilcorp.com Contact Phone: (907)777-8420 Authorized Signature: `7 �� Date: (430/(7 O COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. v 5b1 Plug Integrity ❑ BOP Test❑ Mechanical Integrity Test El Location Clearance 0 r/ Other: L/ �!%s G 2 7 Post Initial Injection MIT Req'd? Yes ❑ No ❑ r L/01 � 1—,,,i—Jen,,-'0°'L:is r“; Spacing Exception Required? Yes ❑ No 2 Subsequent Form Required: C 6 T 0 1 APPROVED BY (7-I It Approved by: 2.�� COMMISSIONER THE COMMISSION Date: 4 i\j \ / > Submit Form and \/v Form 10-403 Revised 4/2017 Approved applicatio is RfiratNAL date of approval. Attach ents in Duplicate • • • Well Prognosis Well: SCU 31-08 Hileorp Alaska,LL' Date: 11/30/2017 Well Name: SCU 31-08 API Number: 50-133-20344-00 Current Status: Rod Pump Oil Well Leg: N/A Estimated Start Date: December 13, 2017 Rig: Moncla 401 Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 181-099 First Call Engineer: Ted Kramer (907) 777-8420(0) (985) 867-0665 (M) Second Call Engineer: Chad Helgeson (907) 777-8405 (0) (907) 229-4824 (M) AFE Number: Current Bottom Hole Pressure: 1,690 psi @ 10,281' MD (Based on BHP gauges on 3/27/2016) Max. Potential Surface Pressure: 662 psi (Based on 0.1 gas gradient to surface) Brief Well Summary Soldotna Creek 31-8 was drilled in 1982 to target H8 and H10 oil reserves in the lower part of the Hemlock formation. Initial production from the H8 and H10 sands exceeded 1100 BOPD. Rapid production decline was attributed to asphaltene and/or paraffin deposits that increased in the wellbore as the GOR increased. These deposits were successfully treated with regular xylene stimulations. In 1986, a rig workover was conducted to replace the production packer and restore casing integrity by squeezing the liner lap. A new gas lift completion was run in 1989 to address a leaking packer and tubing. The upper part of the Hemlock formation (H1-4 sands) and the Tyonek G-Zone were perforated through tubing in 2001. The well went off production in 2002 with a suboptimal gas lift design unable to lift fluid to surface.The well was converted to Rotaflex Rod Pump in February 2013. In June 2014,the%", 7/8",and 1" rod string was replaced. In September 2016,the well stopped producing due to a deep rod part which was repaired in October 2016. This well failed again earlier this year. Hilcorp rigged up on this well in September and replaced a broken rod and the pump. The well failed on startup due to sucking in solids in the rod pump and locking up the pump. • The purpose of this work/sundry is to replace the Stuck pump and replace the%" rod portion of the rod string. Notes Regarding Wellbore Condition • Well is currently not producing on rod pump (suspected stuck pump). Workover Rig Procedure: 1. Blow-down any pressure on the well and shoot fluid level (echometer) on casing. 2. Roll back Rotoflex pumping unit, uncouple and LOTO motor. 3. MIRU Moncla #401 WO Rig. 4. Nipple up rod stride head. tyU 5. LD polish rod and pull EL rods to pull pump. Rack back the rods in basket,except for the%" RODS. cr Lay these rods down and replace. Lay down stuck Rod Pump. 6. Flush tubing with 8.4 ppg produced fluid. 7. PU and inspect existing dip tube. 8. PU new 1-3/4" rod pump with memory gauges. 9. RIH with rod string(sinker bars, new 3/4",existing 7/8" and existing 1"). • • • Well Prognosis Well: SCU 31-08 Hilcorp Alaska,LL Date: 11/30/2017 10. Space out the rods, install existing polish rod. 11. Test pump to 700 psig for 5 minutes to confirm seated in profile 12. ND rod stripper, install surface equipment onto well and test to 1,500 psi. 13. RD Moncla#401 WO Rig. 14. Roll up Rotoflex pumping unit, recouple, and remove LOTO on motor. 15. Return to production with same surface safety system as previously installed. 16. Replace IA x OA pressure gauge if removed (7-5/8"x 10-3/4"). Attachments: 1. Schematic • Soldotna Creek Unit 41110 Well SCU 31-08 Comletion . 11ACTUAL SCHEMATIC PTD:p 181 099 n:2/27/2013 Hilrnru Alaska.LLC API: 50-133-20344-00 CASING DETAIL RKB= 19.50'/GL=128'AMSL Size Wt Grade Conn ID Top Btm A ?1 20" 94# H-40 - 19.124" Surface 72' 10-3/4" 40.5# K-55 - 10.050" Surface 3,354' 7-5/8" 33.7# S-95 - 6.765" Surface 7-5/8" 26.4# N-80 - 6.969" B 20" 7-5/8" 29.7# N-80 - 6.875" 10,452' 5-1/2" 20# N-80 - 4.778" 10,246' 10,902' TUBING DETAIL 2 — 2-7/8" 6.5# L-80 EUE 8RD 2.441" Surface 10,417' 10-3/4" 2' g Liner Top JEWELRY DETAIL C 10,246' No. Depth Length ID OD Item 1 19.5' 0.66 2.441 Tubing Hanger 2 2,501' 2.32 2.430 4.00 Chemical Injection Mandrel 3 10,417' 0.65 2.441 3.50 Seating Nipple D _ G2 4 10,418' 2.32 2.441 4.50 Tubing Anchor(Set 19k tension) E l��i 5 10,421' 0.35 2.992 3.50 Crossover XO 2-7/8"Box 8rd x3-1/2"Pin 8rd y 6 10,421' 4.00 2.992 3.50 Slotted Sub AM _ 7 10,425' 63.43 2.992 3.50 2 jts 3-1/2"Tubing V 3 8 10,489' 0.44 2.992 3.80 Bull Plug 4 1 l 5 F irtill 6 IIH1 ROD DETAIL 7�7 5/8" No. Depth Length OD Item 8 A 15' 40' 1-1/2" Polished Rod,30'in well H2/3 B 55' 450' 1" 1"x 25'EL Sucker rods w/ 3 XL guides per rod 505' 2,825' 1" 1"x 25'EL Sucker rods w/"No"XL guides per rod 3,330' 3,550' 7/8" 7/8"x 25'EL Sucker rods w/ 3 XL guides per rod 6,880' 750' 3/4" 3/4"x 25'EL Sucker rods w/ 3 XL guides per rod H4/5 7,630' 250' 3/4" 3/4"x 25'EL Sucker rods w/ 12 XL guides per rod 7,880' 2,175' 3/4" 3/4"x 25'EL Sucker rods w/ 3 XL guides per rod H6 C 10,055' 300' 1-1/2" 1-1/2"x 25'K Bars(weight bars) Tag Fill @ 10,613' D 10,355' 32.5' 1" 1"x 30"Stabilizer Bar w/%"Pins Sand&Perf Debris E 10,388' 42' 1-3/4" 1-3/4"x 42'Insert Pump,RHBC Pump#5178 w/PA Ring 2/26/13 3.5'3,5:35f4rly H8 80 PA Ring,Sand Seal,2-1/2"x 1-3/4"x 36"x 36-1/2"x 37" 1•ti•YL•1.1 'r•r•J•r•J•J.} RHBC(NEW 10/13/16) r•r•J•r•J•J•r {ir rr3r r�+ F 10,430' 16' 1-1/2" Dip Tube r}rrtirtir:.'t? 1•ti•1•ti•ti...., 'r•r•J•r•J•rM H8 •:::::::::::::::::4; 'f•r•r•r•r•r• ti.ti.ti.tiPP:: :{{{{{r{:{{{{• r•r•r•r•r•r•r, 'PAPPPP. 1'�'�'�'�'� H8 1:rJtirJJyr• r.r.r.f.J.r.f r:f1r1f:f1r:4. 1.1.1.1.1.1.. 1•r•J•r•r•J•r H8 fl ftiftiftiftir j` �.:fti�1f:�.f.f ::f~l�ltr:r.:: 1.1.1.1.1.1•' r.r•J•r•J•J.r 1.1.1.1.1.1., H 10 :•r•r•r•r•r•r r:r~:::::i.r �ISSV:55%ii; ti 1 L L ti'tfti f1PP:4 4..r•r•r•r•r•rY•r•r•r•r•r•r1.1.1.1.1.1..tirtirtir PP:: r•r•J•r•r•J•r 'r�r~J1r1J:JY 1.1.1.1.1.1.. '111:::44 PERFORATION DETAIL ON NEXT PAGE 'r1rrrJr4: ltirtiJtirtirtir1t '1.r.r•r.r.�'.r 1.1.1.1.1.1•' :tir•.rtirtiftill•. *1:�Y1-1�ti�' NOTE:The Surface Casing annulus was used to down squeeze the 5-1/2" liner lap during the 1986 workover of this well. q PBTD=10,854'MD;10,734'TVD TD=10,904'MD;10,783'TVD MAX HOLE ANGLE=17 deg Downhole Revised:06/20/14 Updated by JEK 10/14/16 Soldotna Creek Unit II Well SCU 31-08 0 H • ACTUAL SCHEMATIC Comp181 099 letion n:2/27/2013 PTD Bileoro Alaska,LLC API: 50-133-20344-00 PERFORATION HISTORY(DIL) Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt spf Comments Date G1 10,374' 10,384' 10,267' 10,277' 10' 6 2"PJ HC,60 deg 4/5/2001 H1 10,442' 10,448 10,333' 10,339' 6' 6 3-3/8"HC 60 deg 2/27/13 1-11 10,445' 10,451' 10,336' 10,342' 6' 6 2"PJ HC,60 deg 4/5/2001 H2/3 10,467' 10,515' 10,357' 10,404' 48' 6 2"PJ HC,60 deg 4/5/2001 H2/3 10,469' 10,514' 10,359' 10,403' 45' 6 3-3/8"HC 60 deg 2/27/13 H4/5 10,532' 10,580' 10,420' 10,467' 48' 6 3-3/8"HC 60 deg 2/27/13 H5 10,534' 10,565' 10,422' 10,452' 31' 6 1-11/16"HC 11/5/1999 10,565' 10,580' 10,452' 10,467' 15' 4 1-11/16"HC 2/23/1998 H6 10,596' 10,610' 10,482' 10,496' 14' 4 2-1/8"Enerjet 6/8/1995 H8 10,616' 10,634' 10,502' 10,519' 18' 4 2-18/"DA Slimkone 5/10/1983 6 3-3/8"Baker TCG 8/4/1986 H8 10,664' 10,672' 10,549' 10,556' 8' 4 2-18/"DA Slimkone 5/10/1983 6 3-3/8"Baker TCG 8/4/1986 H8 10,695' 10,703' 10,579' 10,587' 8' 4 2-18/"DA Slimkone 5/10/1983 4 3-3/8"Baker TCG 8/4/1986 H8 10,706' 10,710' 10,590' 10,593' 4' 4 2-18/"DA Slimkone 5/10/1983 6 3-3/8"Baker TCG 8/4/1986 H10 10,726' 10,732' 10,609' 10,615' 6' 4 2-18/"DA Slimkone 10/7/1982 6 3-3/8"Baker TCG 8/4/1986 Downhole Revised:06/20/14 Updated by JEK 10/14/16 STATE OF ALASKA RECEIVED AL OIL AND GAS CONSERVATION COM•ION REPORT OF SUNDRY WELL OPERATIONS OCT 3 0 2017 1.Operations Abandon U Plug Perforations U Fracture Stimulate U Pull Tubing U A06 io t utdown U Performed: Suspend ❑ Perforate El Other Stimulate ❑ Alter Casing El Change Approved Program ❑ Plug for Redrill ❑ srforate New Pool ❑ Repair Well ❑I Re-enter Susp Well ❑ Other: Pump Repair/Parted Rods 2 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development Q Exploratory ❑ 181-099 3.Address: 3800 Centerpoint Dr,Suite 1400 Anchorage, Stratigraphic El Service ❑ 6.API Number: AK 99503 50-133-20344-00 7.Property Designation(Lease Number): 8.Well Name and Number: FEDA028997 Soldotna Creek Unit(SCU)31-08 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Swanson River Field/Hemlock Oil 11.Present Well Condition Summary: Total Depth measured 10,904 feet Plugs measured N/A feet true vertical 10,783 feet Junk measured 10,627(fill) feet Effective Depth measured 10,854 feet Packer measured 10,421 feet true vertical 10,734 feet true vertical 10,313 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 40' 20" 72' 72' Surface 3,354' 10-3/4" 3,354' 3,354' 3,130 psi 1,580 psi Intermediate Production 10,452' 7-5/8" 10,452' 10,343' 6,020 psi 3,400 psi Liner 656' 5-1/2" 10,902' 10,781' 9,190 psi 8,830 psi Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic Tubing(size,grade,measured and true vertical depth) 2-7/8" 6.4#L-80 10,564'MD 10,451'TVD 10,421'MD .." Packers and SSSV(type,measured and true vertical depth) Anchor 10,313'TVD N/A N/A 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/ASCANNE ` 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 160 140 Subsequent to operation: 20 16 198 170 230 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory Developments Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil Q • Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 317-400 Authorized Name: Chad Helgeson 777-8405 Contact Name: Ted Kramer Authorized Title: Operations Manager Contact Email: tkramer@hilcorp.com Authorized Signature: �� Date: 10/21/17 Contact Phone: 777-8420 Form 10-404 Revised 4/2017 �f /1/'/7RBD S L v t.:,;',1 _ 2 20 17 Submit Original Only ffJ 4#1 (0ti/7 • • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date SCU 31-08 Moncla 401 50-133-20344-00 181-099 9/25/17 9/27/17 Daily Operatrons 471117 09/25/2017- Monday Hold safety meeting. PTW.Spot in. Lay pit liner. RU Moncla 401.Start Bleeding down tubing for 2 hrs. Production tubing stand pipe/flow line rigged down prior to arrival. Did not get SITP prior to bleeding down. Well is bled down. Finish rigging up. Start pulling rods. Did not see over pull to unseat pump. Reading 25k on weight gauge. Looks like rods are parted. Stack back triples in derrick. Pulled 131 rods of 1", 141 of 7/8",43 of 3/4", 6', 8', 6' pups joints. Total rod footage pulled 7897'. Broken end of rod was at rod collar. Looking at 5/8" OD fishing profile. No grapple with weatherford overshot box. Called Knight Oil Tools. Confirmed they have the correct overshot for fish detail. Pull surface equipment rod valves and install TIW and 1502 cap. Clean/Secure location. SDFN. Meeting Knight tool hand at shop to get overshot. 09/26/2017 Tuesday PTW. Hold safety meeting. Discuss job procedure. Make up Knight 2 29/32" series 10 overshot with 1 5/8" grapple and cut lip guide. 44k down weight,46k up weight prior to latching.Attempt to work overshot on rod collar.Saw slight over pull of 50k with split block. Well did not go on vac. Couldn't seem to latch. POOH to surface. Pulled 7847' of rods. Should have pulled 7921'. No overshot. Pin end of 3/4" rod broke while attempting to fish. Left two 25' 3/4" rods and overshot in hole. Good indication overshot is latched but rod broke at road threads. Fishing OD size down hole is 1.5". Make up weatherford overshot series 10 overshot with 1.5"grapple. RIH, tagged fish, turn rod string while slacking off. PU over pull. 44k free up weight. Pump pulled off seat at 69K with split block. Well is on vac.Trip Rods OOHh. Pump at surface. Break down pump and over shot. New Rod pump on location. Welded coupling on bottom of dip tube had no memory gauges at surface. No memory gauges were installed when parted rod was replaced in 10-2016. Break down over shots. New pump mobilized to location. Location secure. 09/27/2017-Wednesday Safety meeting. PTW. RIH with existing rods, replace 4-3/4 " rods. PU polish rod. RIH, collapse pump strike and tag. Tap down on pump to set seals. Pick up and space out 34" from pump tag. Measurement from cement slab to top of polished rod 154". Fill tubing with produced water. Stroke pump. PT using pump to 700 psi for 5 minutes. 1,500 psi for 5. Good PT. Start rigging down. Clean cellar with Hotsy pressure washer. Moncla 401 rigged down. Directed to help production slide rotoflex forward and install surface piping. Move Moncla 401 to SCU 12A-04. SDFN. New pump details.: PUMP#5365, Pump Type = RHBC, Size= 25-175-RHBC-36-4-6"-6", pic installed in 0 drive. Soldotna Creek Unit 111 0 • Well SCU 31-08 ACTUAL SCHEMATIC p181 099 letion n:2/27/2013 PTD Ililearn Alaska.LLC API: 50-133-20344-00 CASING DETAIL RKB= 19.50'/GL=128'AMS L Size Wt Grade Conn ID Top Btm 20" 94# H-40 19.124" Surface 72' A 1 10 3/4" 40.5# K-55 S-95 10.050" Surface 3,354' 7-5/8" 33.7# 6.765" Surface 7-5/8" 26.4# N-80 - 6.969" B 20,. 7-5/8" 29.7# N-80 - 6.875" 10,452' 5-1/2" 20# N-80 - 4.778" 10,246' 10,902' TUBING DETAIL 2 — 2-7/8" 6.5# L-80 EUE 8RD 2.441" Surface 10,417' 10-3/4" I S g Liner Top JEWELRY DETAIL C 10,246' No. Depth Length ID OD Item 1 19.5' 0.66 2.441 Tubing Hanger 2 2,501' 2.32 2.430 4.00 Chemical Injection Mandrel 3 10,417' 0.65 2.441 3.50 Seating Nipple D _ = G2 4 10,418' 2.32 2.441 4.50 Tubing Anchor(Set 19k tension) 5 10,421' 0.35 2.992 3.50 Crossover X0 2-7/8"Box 8rd x3-1/2"Pin 8rd E 6 10,421' 4.00 2.992 3.50 Slotted Sub as 7 10,425' 63.43 2.992 _ 3.50 2 jts 3-1/2"Tubing 1 ;° 3 fb 8 10,489' 0.44 2.992 3.80 Bull Plug 1 i 5 4 A '', F1 ' 6 iri = Hi ROD DETAIL L 7 7-5/8" No. Depth Length OD Item 8 A 15' 40' 1-1/2" Polished Rod,30'in well H2/3 B 55' 450' 1" 1"x 25'EL Sucker rods w/ 3 XL guides per rod 505' 2,825' 1" 1"x 25'EL Sucker rods w/"No"XL guides per rod 3,330' 3,550' 7/8" 7/8"x 25'EL Sucker rods w/ 3 XL guides per rod 6,880' 750' 3/4" 3/4"x 25'EL Sucker rods w/ 3 XL guides per rod H4/5 7,630' 250' 3/4" 3/4"x 25'EL Sucker rods w/ 12 XL guides per rod 7,880' 2,175' 3/4" 3/4"x 25'EL Sucker rods w/ 3 XL guides per rod H6 C 10,055' 300' 1-1/2" 1-1/2"x 25'K Bars(weight bars) Tag Fill @ 10,613' D 10,355' 32.5' 1" 1"x 30"Stabilizer Bar w/%"Pins Sand&Perf Debris E 10,388' 42' 1-3/4" 1-3/4"x 42'Insert Pump,RHBC Pump#5178 w/PA Ring 2/26/13 f:}}}}r}p}}:'}' H8 80 PA Ring,Sand Seal,2-1/2"x 1-3/4"x 36"x 36-1/2"x 37" ,rti f1r1rti fti ftile ~.1.1.1.1.1.. RHBC(NEW 10/13/16) r•r1r~rtir.r•r F 10,430' 16' 1-1/2" Dip Tube 1.1.1.1.1.1.' •ti: 1f1r1r11' '•r•r•r.r•r•r 'rl}':.V.�6, H8 i�ti jS f1.f1 ftir Yi 1K.5..5..1•{•' ;'r'r'r'r'r�{. l.r•r•r•r•51 .rtijtiflftif5�ftif L 1.1.1.1.1.1.• 0•r•r.r•r.r•r '::::::::::::::*1:; H8 1.1.1.1. .1.' 1::::ftirtir::4:: '�•r•r•r•r•r•r stc;s1tif1}r1r1ti1 655:.."35i5:::73:1—, H10 H 10 1:::::1r1r:r:} ese•rlfftif 1::::::::::::::::a 1.1.1...1.1•' .r r1.1r::::PS 'r•r•r•r.r•r•r r1ryr1rtir1r1r ltifyr1ftif1tM 1.1.1.1.1.1•' r•r•r•r•r•r•r .tiftir;ftiftirtif PERFORATION DETAIL ON NEXT PAGE .tiftiftiftiftir*f 1Pf r1ltif1r1f .rtirtirtirtir;r;f 1.1.1.1.1.1.' :f1.11?1'1j1f' NOTE:The Surface Casingannulus was used to down squeeze the 4,.r.,. .$' \ 5-1/2" q PBTD=10,854'MD;10,734'TVD liner lap during the 1986 workover of this well. TD=10,904'MD;10,783'TVD MAX HOLE ANGLE=17 deg Downhole Revised:06/20/14 Updated by JEK 10/14/16 Soldotna Creek Unit • Well SCU 31-08 ACTUAL SCHEMATIC Completion 181-099 n:2/27/2013 PTD HiIcora Alaska,LLC. API: 50-133-20344-00 PERFORATION HISTORY(DIL) Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt spf Comments Date G1 10,374' 10,384' 10,267' 10,277' 10' 6 2"P1 HC,60 deg 4/5/2001 H1 10,442' 10,448 10,333' 10,339' 6' 6 3-3/8"HC 60 deg 2/27/13 H1 10,445' 10,451' 10,336' 10,342' 6' 6 2"PJ HC,60 deg 4/5/2001 H2/3 10,467' 10,515' 10,357' 10,404' 48' 6 2"PJ HC,60 deg 4/5/2001 H2/3 10,469' 10,514' 10,359' 10,403' 45' 6 3-3/8"HC 60 deg 2/27/13 H4/5 10,532' 10,580' 10,420' 10,467' 48' 6 3-3/8"HC 60 deg 2/27/13 H5 10,534' 10,565' 10,422' 10,452' 31' 6 1-11/16"HC 11/5/1999 10,565' 10,580' 10,452' 10,467' 15' 4 1-11/16"HC 2/23/1998 H6 10,596' 10,610' 10,482' 10,496' 14' 4 2-1/8"Enerjet 6/8/1995 H8 10,616' 10,634' 10,502' 10,519' 18' 4 2-18/"DA Slimkone 5/10/1983 6 3-3/8"Baker TCG 8/4/1986 H8 10,664' 10,672' 10,549' 10,556' 8' 4 2-18/"DA Slimkone 5/10/1983 6 3-3/8"Baker TCG 8/4/1986 H8 10,695' 10,703' 10,579' 10,587' 8' 4 2-18/"DA Slimkone 5/10/1983 4 3-3/8"Baker TCG 8/4/1986 H8 10,706' 10,710' 10,590' 10,593' 4' 4 2-18/"DA Slimkone 5/10/1983 6 3-3/8"Baker TCG 8/4/1986 H10 10,726' 10,732' 10,609' 10,615' 6' 4 2-18/"DA Slimkone 10/7/1982 6 3-3/8"Baker TCG 8/4/1986 Downhole Revised:06/20/14 Updated by JEK 10/14/16 • QF Tit I//7: THE STATE Alaska Oil and Gas Of T AsKA Conservation Commission � fI2 - - 333 West Seventh Avenue " . GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 OF La- Main: 907.279.1433 A SI" Fax: 907.276.7542 www.aogcc.alaska.gov Chad Helgeson Operations Manager SCANNED SEP 0 12017, Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Swanson River Field, Hemlock Oil Pool, SCU 31-08 Permit to Drill Number: 181-099 Sundry Number: 317-400 Dear Mr. Helgeson: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, aletfT Cathy P. Foerster Commissioner DATED this L3iday of August, 2017. RBDNIS \V AU3 3 0 2017 r 0 RECEIVED STATE OF ALASKA AUG 211,017 ALASKA OIL AND GAS CONSERVATION COMMISSION . 3 Z9i 17 APPLICATION FOR SUNDRY APPROVALS AGC 20 AAC 25.280 1.Type of Request: Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Repair Well ❑✓ • Operations shutdown❑ Suspend ❑ Perforate 0 Other Stimulate 0 Pull Tubing 0 Change Approved Program 0 Plug for Redrill ❑ Perforate New Pool 0 Re-enter Susp Well ❑ Alter Casing 0 Other: Pump Repair/Parted Rods❑2 • 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska,LLC Exploratory ❑ Development Q • 181-099 • 3.Address: 3800 Centerpoint Dr,Suite 1400 Stratigraphic 0 Service ❑ 6.API Number: Anchorage Alaska 99503 50-133-20344-00 • 7. If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? CO 123B IDSoldotna Creek Unit(SCU)31-08 Will planned perforations require a spacing exception? Yes El No 9.Property Designation(Lease Number): 10.Field/Pool(s): FEDA028997 • Swanson River Field/Hemlock Oil 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): 10,904' • 10,783' • 10,854' 10,734' 662 psi N/A 10,627'(fill) Casing Length Size MD TVD Burst Collapse Structural Conductor 40' 20" 72' 72' Surface 3,354' 10-3/4" 3,354' 3,354' 3,130 psi 1,580 psi Intermediate Production 10,452' 7-5/8" 10,452' 10,343' 6,020 psi 3,400 psi Liner 656' 5-1/2" 10,902' 10,781' 9,190 psi 8,830 psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic See Attached Schematic 2-7/8" 6.5#/L-80 10,564' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): Anchor; N/A 10,421'MD/10,313'TVD; N/A 12.Attachments: Proposal Summary ❑✓ Wellbore schematic ❑✓ 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Stratigraphic 0 Development 2• Service 0 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: September 4,2017 OIL ❑ WINJ ❑ WDSPL ❑ Suspended 0 16.Verbal Approval: Date: GAS 0 WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Chad Helgeson 777-8405 Contact Name: Ted Kramer Authorized Title: Operations Manager Contact Email: tkramerahilcoro.com Contact Phone: 777-8420 Authorized Signature:/ 4 Date: gyZip7 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes 0 No ❑ RBDMS Spacing Exception Required? Yes ❑ No v Subsequent Form Required: , D `v U 0 2017 APPROVED"CBY Approved by: 67,)9....e.,414........ COMMISSIONER THE COMMISSION Date: g.. e__. —/ 7 IA ./_ g 1317 Form 10-403 Revised 4/2017 0 Rio6fftAiIhd it for 12 months from the date of approval. b 251 1 i 1 Form and Submit s Submit plicae • • Well Prognosis Well: SCU 31-08 Hilcorp Alaska,LLI Date:8/21/2017 Well Name: SCU 31-08 API Number: 50-133-20344-00 Current Status: Rod Pump Oil Well Leg: N/A Estimated Start Date: September 4, 2017 Rig: Moncla 401 Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 181-099 First Call Engineer: Ted Kramer (907) 777-8420 (0) (985) 867-0665 (M) Second Call Engineer: Chad Helgeson (907) 777-8405 (0) (907) 229-4824 (M) AFE Number: Current Bottom Hole Pressure: 1,690 psi @ 10,281' MD (Based on BHP gauges on 3/27/2016) Max. Potential Surface Pressure: 662 psi (Based on 0.1 gas gradient to surface) Brief Well Summary Soldotna Creek 31-8 was drilled in 1982 to target H8 and H10 oil reserves in the lower part of the Hemlock formation. Initial production from the H8 and H10 sands exceeded 1100 BOPD. Rapid production decline was attributed to asphaltene and/or paraffin deposits that increased in the wellbore as the GOR increased. These deposits were successfully treated with regular xylene stimulations. In 1986, a rig workover was conducted to replace the production packer and restore casing integrity by squeezing the liner lap. A new gas lift completion was run in 1989 to address a leaking packer and tubing. The upper part of the Hemlock formation (H1-4 sands) and the Tyonek G-Zone were perforated through tubing in 2001. The well went off production in 2002 with a suboptimal gas lift design unable to lift fluid to surface.The well was converted to Rotaflex Rod Pump in February 2013. In June 2014,the%", 7/8", and 1" rod string was replaced. In September 2016,the well stopped producing due to a deep rod part which was repaired in October 2016. Earlier this month from,this well quit producing. A suspected worn pump or deep rod part is believed to be the issue. The purpose of this work/sundry is to replace the worn pump or repair parted rods for this Rotaflex Rod Pump well. Notes Regarding Wellbore Condition • Well is currently not producing on rod pump (suspect parted rods near pump). Workover Rig Procedure: 1. Blow-down any pressure on the well and shoot fluid level (echometer) on casing. 2. Roll back Rotoflex pumping unit, uncouple and LOTO motor. 3. MIRU Moncla #401 WO Rig. 4. Nipple up rod stripper head. 1- 5. LD polish rod and pull EL rods to pull pump. Rack back the rods in basket. 6. If parted deep, MU overshot and grapple. Fish parted rods in the 3/4" rods or at the pump. 7. LD and inspect pump, dip tube, and all pulled rods. 8. PU existing dip tube. 9. PU new 1-3/4" rod pump with memory gauges.'- 10. RIH with existing tapered rod string(sinker bars, 3/4", 7/8" and 1"). 11. Space out the rods, install existing polish rod. . • • Well Prognosis Well: SCU 31-08 Hilcorp Alaska,LLQ Date:8/21/2017 12. Test pump to 700 psig for 5 minutes to confirm seated in profile 13. ND rod stripper, install surface equipment onto well and test to 1,500 psi. 14. RD Moncla#401 WO Rig. 15. Roll up Rotoflex pumping unit, recouple, and remove LOTO on motor. 16. Return to production with same surface safety system as previously installed. 17. Replace IA x OA pressure gauge if removed (7-5/8" x 10-3/4"). Attachments: 1. Schematic • Soldotna Creek Unit • 14 H . fil Well SCU 31-08 ACTUAL SCHEMATIC PTD Comp181 099 letion n:2/27/2013 Hiicoro Alaska.LLC API: 50-133-20344-00 CASING DETAIL RKB= 19.50'/GL= 128'AMS L Size Wt Grade Conn ID Top Btm A a 1 20" 94# H-40 - 19.124" Surface 72' II 1 - " K-- 00" Surface 3,354' 7-5/8" 33.7# S9555 6.765" Surface 107-5/83/4" 26.4# N-80 6.969.05" B 20" 7-5/8" 40.5#29.7# N-80 6.875" 10,452' 10,246' 10,902' li — - 5-1/2" 20# N-80 4.778" TUBING DETAIL 1 2 2-7/8" 6.5# L-80 EUE 8RD 2.441" Surface 10,417' 10-3/4" Ig g Liner Top JEWELRY DETAIL C 10,246' No. Depth Length ID OD Item 1 19.5' 0.66 2.441 Tubing Hanger 2 2,501' 2.32 2.430 4.00 Chemical Injection Mandrel 3 10,417' 0.65 2.441 3.50 Seating Nipple D G2 4 10,418' 2.32 2.441 4.50 Tubing Anchor(Set 19k tension) E 101 5 10,421' 0.35 2.992 3.50 Crossover X0 2-7/8"Box 8rd x3-1/2"Pin 8rd 6 10,421' 4.00 2.992 3.50 Slotted Sub 7 10,425' 63.43 2.992 3.50 2 jts 3-1/2"Tubing 3 8 10,489' 0.44 2.992 3.80 Bull Plug tk 4 15 F - 6 T H1ROD DETAIL " +1 7 7_5/8" No. Depth Length OD Item 8 A 15' 40' 1-1/2" Polished Rod,30'in well H2/3 B 55' 450' 1" 1"x 25'EL Sucker rods w/ 3 XL guides per rod 505' 2,825' 1" 1"x 25'EL Sucker rods w/"No"XL guides per rod 3,330' 3,550' 7/8" 7/8"x 25'EL Sucker rods w/ 3 XL guides per rod 6,880' 750' 3/4" 3/4"x 25'EL Sucker rods w/ 3 XL guides per rod H4/5 7,630' 250' 3/4" 3/4"x 25'EL Sucker rods w/ 12 XL guides per rod 7,880' 2,175' 3/4" 3/4"x 25'EL Sucker rods w/ 3 XL guides per rod C 10,055' 300' 1-1/2" 1-1/2"x 25'K Bars(weight bars) Tag Fill @ 10,613' H6 D 10,355' 32.5' 1" 1"x 30"Stabilizer Bar w/%"Pins Sand&Perf Debris E 10,388' 42' 1-3/4" 1-3/4"x 42'Insert Pump,RHBC Pump#5178 w/PA Ring 2/26/13 r;f}f}f}f}r?r• H8 80 PA Ring,Sand Seal,2-1/2"x 1-3/4"x 36"x 36-1/2"x 37" 1.1.1.1.1.1' 'r•r•r•r•r•r•} r::f;,I f}f RHBC(NEW 10/13/16) ~ 5.3% F 10,430' 16' 1-1/2" Dip Tube 'r•r•r•r•r.r•r •r11:f1f:f}}1r l•r•r•r•r•r•r, ..7::::::::Y*??:r?r1f{:1r1: HS r1rrrr1rr, rrrrrrr, rfr1rf' H8 'r•r•r•rr•r•r ,.1.1.1.1.1.1.. r1r1r1r1r1r1r, r1r:P.741{r;r• H8 rrr1rfr1.v• r1rf::::::..% :: :1fir?• •r•r•r.r.r•r . .1.1.1.1.1•' r{? { ?{?T' H 10 r•r.r•r•r•rw 'r1rtiryr1}':}'11' •ftilti fti fti fti fti f .. .1.1. .1.1.• r1rr1rr1:41: rrr1r•1.T., frr1fr1r1f' rrr1r1r1rr, •r1ff1? 1}•}r1:::::.11111414•:...•r,r,r,r,r, PERFORATION DETAIL ON NEXT PAGE ..*::::::::::41:4 4, r•r•r•r•r•r•r .}ti1:}tirtir:rti} .1.1.1.1. .1.' NOTE:The Surface Casing annulus was used to down squeeze the 1, 5-1/2" liner lap during the 1986 workover of this well. PBTD=10,854'MD;10,734'TVD TD=10,904'MD;10,783'ND MAX HOLE ANGLE=17 deg Downhole Revised:06/20/14 Updated byJEK 10/14/16 • Soldotna Creek Unit u 14 • • Well SCU 31-08 ACTUAL SCHEMATIC PTD p181 099 letion Ran:2/27/2013 Hilcoro Alaska.LLC API: 50-133-20344-00 PERFORATION HISTORY(DIL) Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt spf Comments Date G1 10,374' 10,384' 10,267' 10,277' 10' 6 2"PJ HC,60 deg 4/5/2001 H1 10,442' 10,448 10,333' 10,339' 6' 6 3-3/8"HC 60 deg 2/27/13 H1 10,445' 10,451' 10,336' 10,342' 6' 6 2"PJ HC,60 deg 4/5/2001 H2/3 10,467' 10,515' 10,357' 10,404' 48' 6 2"PJ HC,60 deg 4/5/2001 H2/3 10,469' 10,514' 10,359' 10,403' 45' 6 3-3/8"HC 60 deg 2/27/13 H4/5 10,532' 10,580' 10,420' 10,467' 48' 6 3-3/8"HC 60 deg 2/27/13 H5 10,534' 10,565' 10,422' 10,452' 31' 6 1-11/16"HC 11/5/1999 10,565' 10,580' 10,452' 10,467' 15' 4 1-11/16"HC 2/23/1998 H6 10,596' 10,610' 10,482' 10,496' 14' 4 2-1/8"Enerjet 6/8/1995 H8 10,616' 10,634' 10,502' 10,519' 18' 4 2-18/"DA Slimkone 5/10/1983 6 3-3/8"Baker TCG 8/4/1986 H8 10,664' 10,672' 10,549' 10,556' 8' 4 2-18/"DA Slimkone 5/10/1983 6 3-3/8"Baker TCG 8/4/1986 H8 10,695' 10,703' 10,579' 10,587' 8' 4 2-18/"DA Slimkone 5/10/1983 4 3-3/8"Baker TCG 8/4/1986 H8 10,706' 10,710' 10,590' 10,593' 4' 4 2-18/"DA Slimkone 5/10/1983 6 3-3/8"Baker TCG 8/4/1986 H10 10,726' 10,732' 10,609' 10,615' 6' 4 2-18/"DA Slimkone 10/7/1982 6 3-3/8"Baker TCG 8/4/1986 Downhole Revised:06/20/14 Updated by JEK 10/14/16 STATE OF ALASKA AIL OIL AND GAS CONSERVATION COM SION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon H Repair Well U Plug Perforations U Perforate U Other U Pump Repair/ Performed: Alter Casing ❑ Pull Tubing❑ Stimulate-Frac ❑ Waiver ❑ Time Extension❑ Parted Rods Change Approved Program ❑ Operat.Shutdown❑ Stimulate-Other ❑ Re-enter Suspended Well❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development Q Exploratory ❑ 181-099 3.Address: 3800 Centerpoint Drive,Suite 100 Stratigraphic El Service ❑ 6.API Number: Anchorage,Alaska 99504 50-133-20344-00 7.Property Designation(Lease Number): 8.Well Name and Number: FEDA028997 Soldotna Creek Unit(SCU)31-08 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Swanson River Field/Hemlock Oil 11.Present Well Condition Summary: Total Depth measured 10,904 feet Plugs measured N/A ReECE1VED true vertical 10,783 feet Junk measured 10,627(fill) feet NOV152016 Effective Depth measured 10,854 feet Packer measured 10,421 feet true vertical 10,734 feet true vertical 10,313 fe °°D GCC Casing Length Size MD TVD Burst Collapset Structural Conductor 40' 20" 72' 72' Surface 3,354' 10-3/4" 3,354' 3,354' 3,130 psi 1,580 psi Intermediate Production 10,452' 7-5/8" 10,452' 10,343' 6,020 psi 3,400 psi Liner 656' 5-1/2" 10,902' 10,781' 9,190 psi 8,830 psi Perforation depth Measured depth See Attached Schematic SCANNED MAR , 6 2 O, Z True Vertical depth See Attached Schematic `` `' Tubing(size,grade,measured and true vertical depth) 2-7/8" 6.4#L-80 10,564'MD 10,451'TVD 10,421'MD Packers and SSSV(type,measured and true vertical depth) Anchor 10,313'TVD N/A N/A 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 14 23 186 190 200 Subsequent to operation: 15 21 237 155 175 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run N/A Exploratory❑ Development 2 Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil 0 Gas ❑ WDSPL❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 316-496 Contact Joe Kaiser-777-8393 Email jkaiser0.hilcorp.com Printed Name Chad Helgeson Title Operations Manager Signature / ‘°/' "1 -- Phone 907-777-8405 Date A/416 Form 10-404 Revised 10/2012 DMS � Submit Original Only f igii4 :,--;47 �-Z�4 kV 1 6 2016 S • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date SCU 31-08 Moncla 401 50-133-20344-00 181-099 10/12/16 10/14/16 Daily Operations: 10/12/2016-Wednesday PJSM, laid containment, disconnected flowline and heat trace. Spotted beam and MIRU Moncla 401. SITP 50psi. RU blowdown trailer and bled off tbg. RU floor and rod handling tools. BO/LD the stuffing box and polished rod. MU rod stripper head and TOH w/ 131 1" EL rods, 142 7/8" EL rods and 26 3/4" EL rods standing back same.The rod part was bewteen#26 and #27 in the 3/4" section.Top of fish is a 3/4" box looking up. Secured well and SDFN. 10/13/2016-Thursday Held PJSM and discussed daily ops. MU a 2-5/16" OS loaded with 1-5/8" grapple catch.TIH w/with same torquing every rod box.Tagged and set down 3K on fish, engaged fish and PU with travel in the pump. Unseated pump. MIRU vac loaded with 50bbls of PW. Pumped 50 bbls down tbg to clean the rod string.TOH w/rod string and LD the rod pump. PU new 1-3/4" rod pump (bucket test good) and TIH replacing rod #25, 26 and 27 in the 3/4" section.Tagged seat nipple and spaced out pump. LD rod stripper head. PU two 8' pony rod, stuffing box and polish rod. Seated pump and spaced out 30' of bottom and secured with rod clamps. Secured well and SDFN. 10/14/2016- Friday Held PJSM, MIRU vac truck and filled tbg with 32bbls of PW. RDMO vac truck. Stroked rod pump with rig and pressured up to 750psi. Held 5mins,good test. Cleared and cleaned rig floor. RU floor and derrick. Loaded Moncla 401 on Weaver Bro's and haul to Moncla's shop. Cleaned and cleared pad. Well to production. • H . Soldotna Creek Unit Well SCU 31-08 • ACTUAL SCHEMATIC PTDp181 099 letion n:2/27/2013 Ililron,Alaska.LLC API: 50-133-20344-00 CASING DETAIL RKB= 19.50'/GL=128'AMSL Size Wt Grade Conn ID Top Btm A I 1 20" 94# H-40 19.124" Surface 72' 10-3/4" 40.5# K-55 10.050" Surface 3,354' 7-5/8" 33.7# S-95 6.765" Surface 7-5/8" 26.4# N-80 - 6.969" B 20 7-5/8" 29.7# N-80 - 6.875" 10,452' 5-1/2" 204 N-80 - 4.778" 10,246' 10,902' TUBING DETAIL 2 2-7/8" 6.54 L-80 EUE 8RD 2.441" Surface 10,417' 10-3/4" g g Liner Top JEWELRY DETAIL C 10,246' No. Depth Length ID OD Item 1 19.5' 0.66 2.441 Tubing Hanger 2 2,501' 2.32 2.430 4.00 Chemical Injection Mandrel 3 10,417' 0.65 2.441 3.50 Seating Nipple D = G2 4 10,418' 2.32 2.441 4.50 Tubing Anchor(Set 19k tension) 5 10,421' 0.35 _ 2.992 3.50 Crossover XO 2-7/8"Box 8rd x3-1/2"Pin 8rd E ( 6 10,421' 4.00 _ 2.992 3.50 Slotted Sub f 7 10,425' 63.43 2.992 3.50 2 jts 3-1/2"Tubing 1i' 3 8 10,489' 0.44 2.992 3.80 Bull Plug 4 I 5 FIL 6 H1 ROD DETAIL z 7 7-5/8" No. Depth Length OD Item -- 8 A 15' 40' 1-1/2" Polished Rod,30'in well H2/3 B 55' 450' 1" 1"x 25'EL Sucker rods w/ 3 XL guides per rod 505' 2,825' 1" 1"x 25'EL Sucker rods w/"No"XL guides per rod 3,330' 3,550' 7/8" 7/8"x 25'EL Sucker rods w/ 3 XL guides per rod 6,880' 750' 3/4" 3/4"x 25'EL Sucker rods w/ 3 XL guides per rod H4/5 7,630' 250' 3/4" 3/4"x 25'EL Sucker rods w/ 12 XL guides per rod 7,880' 2,175' 3/4" 3/4"x 25'EL Sucker rods w/ 3 XL guides per rod H6 C 10,055' 300' 1-1/2" 1-1/2"x 25'K Bars(weight bars) Tag Fill @ 10,613' D 10,355' 32.5' 1" 1"x 30"Stabilizer Bar w/%"Pins Sand&Perf Debris E 10,388' 42' 1-3/4" 1-3/4"x 42'Insert Pump,RHBC Pump#5178 w/PA Ring _ 2/26/13 !f▪}f}}afy}f^' H8 80 PA Ring,Sand Seal,2-1/2"x 1-3/4"x 36"x 36-1/2"x 37" S•\•ti•1•ti• °:{:;:::::S fti RHBC(NEW 10/13/14) :r•r•r•r•r•r• 0::::::::::::::: F 10,430' 16' 1-1/2" Dip Tube 5:?ti▪.ti.5i.ti.ti.ti .. .r.r.r . �~▪1 r r H8 • :f,.r.}.}.r.�ti1tir} :1.1.1.1.1.1 r.r.r.r.r.r. :1.1.1.1.1• :f. • 1. .rtiftir H8 . .▪1tir1tirr1r1rtir r.r.r.r.r.r. v1.1.1.1.1• r•r•r•r•r .rtirtiftiftiftifl H8 1.1.1•L•1• •ftitiltiflfti :f•r•r•r•r•r• 'or;::tirti f}f}fti 1.1.1.1.5. :t;se:0700% H10 G1.1.1.5.5.. .r.r.r.r.r ftiftifti▪rtif{fti PERFORATION DETAIL ON NEXT PAGE i}1.1.1.1.1.1 .r.r.r.r.r. ▪ .1. .1. .1 :f.r•r•r•r.r. :1.1.1.1.1.1 r•r•r•r•r.r. .•1111.11 f r : r•r' NOTE:The Surface Casing annulus was used to down squeeze the 'f•-r•1.1.1.1 .:. 5-1/2" liner lap during the 1986 workover of this well. PBTD=10,854'MD;10,734'TVD _ TD=10,904'MD;10,783'TVD MAX HOLE ANGLE=17 deg Downhole Revised:06/20/14 Updated byJEK 10/14/16 • Soldotna Creek Unit • Well e H ACTUAL S C H E M AT T C WellSCU 31-08 Completion 181 099 n:2/27/2013 PTD Ililcora Alaska,LL( API: 50-133-20344-00 PERFORATION HISTORY(DIL) Zone Top(MD) _ Btm(MD) Top(TVD) Btm(TVD) Amt spf Comments Date G1 10,374' 10,384' 10,267' 10,277' 10' 6 " 2"PJ HC,60 deg 4/5/2001 H1 10,442' 10,448 10,333' 10,339' 6' 6 3-3/8"HC 60 deg 2/27/13 H1 10,445' 10,451' 10,336' 10,342' 6' 6 2"PJ HC,60 deg 4/5/2001 H2/3 10,467' 10,515' 10,357' 10,404' 48' 6 2"PJ HC,60 deg 4/5/2001 H2/3 10,469' 10,514' 10,359' 10,403' 45' 6 3-3/8"HC 60 deg 2/27/13 H4/5 10,532' 10,580' 10,420' 10,467' 48' 6 3-3/8"HC 60 deg 2/27/13 H5 10,534' 10,565' 10,422' 10,452' 31' 6 1-11/16"HC 11/5/1999 10,565' 10,580' 10,452' 10,467' 15' 4 1-11/16"HC 2/23/1998 H6 10,596' 10,610' 10,482' 10,496' 14' 4 2-1/8"Enerjet 6/8/1995 H8 10,616' 10,634' 10,502' 10,519' 18' 4 2-18/"DA Slimkone 5/10/1983 6 _ 3-3/8"Baker TCG 8/4/1986 H8 10,664' 10,672' 10,549' 10,556' 8' 4 2-18/"DA Slimkone 5/10/1983 6 3-3/8"Baker TCG 8/4/1986 H8 10,695' 10,703' 10,579' 10,587' 8' 4 2-18/"DA Slimkone 5/10/1983 4 3-3/8"Baker TCG 8/4/1986 H8 10,706' 10,710' 10,590' 10,593' 4' 4 2-18/"DA Slimkone 5/10/1983 6 _ 3-3/8"Baker TCG 8/4/1986 H10 10,726' 10,732' 10,609' 10,615' 6' 4 2-18/"DA Slimkone 10/7/1982 6 3-3/8"Baker TCG 8/4/1986 Downhole Revised:06/20/14 Updated byJEK 10/14/16 • V OF T1, r S . yam_z.\��\��jy,�� THE STATE Alaska Oil and Gas A.s , s� � . 9,2' ALAConservation Commission f. i,T=P.,�Iia� sKA t �� 333 West Seventh Avenue �z f GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572\ • Main: 907.279.1433 OF ALAS,'P Fax: 907.276.7542 www.aogcc.alaska.gov Chad Helgeson Operations Manager 1 sCAteel FEE 7 Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Swanson River Field, Hemlock Oil Pool, SCU 31-08 Permit to Drill Number: 181-099 Sundry Number: 316-496 Dear Mr. Helgeson: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P. oerster Chair DATED this 2.day of September, 2016. RBDMS (ic/Ut;i 0 3 2016 • 0 RECEIVED ' STATE OF ALASKA S F P 2 7 23\6 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon 0 Plug Perforations ❑ Fracture Stimulate ❑ Repair Well Q " Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other:Pump Repair/Parted Rods P-1- 2.Operator Name: Hilcorp Alaska,LLC 4.Current Well Class: 5.Permit to Drill Number: Exploratory ❑ Development ❑✓ • 181-099 " 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic ❑ Service ❑ 6.API Number: Anchorage,Alaska 99503 50-133-20344-00 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? CO 123B Soldotna Creek Unit(SCU)31-08 • Will planned perforations require a spacing exception? Yes ❑ No ❑✓ 9.Property Designation(Lease Number): 10.Field/Pool(s): FEDA028997 Swanson River Field/Hemlock Oil 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): 10,904' ' 10,783' • 10,854' 10,734' 662 psi N/A 10,613'(fill) Casing Length Size MD TVD Burst Collapse Structural Conductor 40' 20" 72' 72' Surface 3,354' 10-3/4" 3,354' 3,354' 3,130 psi 1,580 psi Intermediate Production 10,452' 7-5/8" 10,452' 10,343' 6,020 psi 3,400 psi Liner 656' 5-1/2" 10,902' 10,781' 9,190 psi 8,830 psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic See Attached Schematic 2-7/8" 6.5#L-80 10,147' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): Anchor;N/A 10,421'MD/10,313'ND;N/A 12.Attachments: Proposal Summary ❑✓ Wellbore schematic Q 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: October 7,2016 OIL E - WINJ ❑ WDSPL 0 Suspended 0 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Joe Kaiser Phone: 907-777-8393 Email jkaiserc hilcorD.com Printed Name Chad Helgeson Title Operations Manager Signature (-7/1/7 /./ ignature /��i// Phone 907-777-8405 Date i/77 / (' COMMISSION USE ONLY / Conditions of approval: Notify Commission so that a representative may witness Sundry Number. 3162 - 1-(94-e Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: +ts - a 12•1 li Post Initial Injection MIT Req'd? Yes 0 No 0t- t Spacing Exception Required? Yes ❑ Nod Subsequent Form Required: / o" ( Li1 RBDMS (11' OCT 0 3 2016 U APPROVED BY Q Approved by; COMMISSIONER THE COMMISSION Date: / • 2 49_/4,6 11 `/6 Submit Form and Form 10-40 evised 11/2015 ' �}p�v�d �cn id for 12 months from the date of approval P. Attachments in Duplicate • • Well Prognosis Well: SCU 31-08 Hilrorp Alaska,LLC Date:9/27/2016 Well Name: SCU 31-08 API Number: 50-133-20344-00 Current Status: Rod Pump Oil Well Leg: N/A Estimated Start Date: October 7th, 2016 Rig: Moncla 401 Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 181-099 First Call Engineer: Joe Kaiser (907)777-8393 (0) (907) 952-8897 (M) Second Call Engineer: Chad Helgeson (907)777-8405 (0) (907) 229-4824 (M) AFE Number: Current Bottom Hole Pressure: 1,690 psi @ 10,281' MD (Based on BHP gauges on 3/27/2015) Max. Potential Surface Pressure: 662 psi (Based on 0.1 gas gradient to surface) Brief Well Summary Soldotna Creek 31-8 was drilled in 1982 to target H8 and H10 oil reserves in the lower part of the Hemlock formation. Initial production from the H8 and H10 sands exceeded 1100 BOPD. Rapid production decline was attributed to asphaltene and/or paraffin deposits that increased in the wellbore as the GOR increased. These deposits were successfully treated with regular xylene stimulations. In 1986, a rig workover was conducted to replace the production packer and restore casing integrity by squeezing the liner lap. A new gas lift completion was run in 1989 to address a leaking packer and tubing. The upper part of the Hemlock formation (H1-4 sands) and the Tyonek G-Zone were perforated through tubing in 2001. The well went off production in 2002 with a suboptimal gas lift design unable to lift fluid to surface.The well was converted to Rotaflex Rod Pump in • February 2013. In June 2014,the%", 7/8", and 1" rod string was replaced. In September 2016,the well stopped producing from a suspected worn pump or deep rod part • The purpose of this work/sundry is to replace the worn pump or repair parted rods for this Rotaflex Rod Pump • well. Notes Regarding Wellbore Condition • Well is currently not producing on rod pump (suspect parted rods near pump). Workover Rig Procedure: 1. Blow-down any pressure on the well and shoot fluid level (echometer)on casing. 2. Roll back Rotoflex pumping unit, uncouple and LOTO motor. 3. MIRU Moncla #401 WO Rig. le5t-e 4. Nipple up rod stripper head. ill- 5. LD polish rod and pull EL rods to pull pump. Rack back the rods in basket. 6. If parted deep, MU overshot and grapple. Fish parted rods in the 3/4" rods or at the pump. 7. LD and inspect pump, dip tube, and all pulled rods. 8. PU existing dip tube. 9. PU new 1-3/4" rod pump with memory gauges. 10. RIH with existing tapered rod string(sinker bars, 3/4",7/8" and 1"). 11. Space out the rods, install existing polish rod. 12. Test pump to 700 psig for 5 minutes to confirm seated in profile • • Well Prognosis Well: SCU 31-08 Hilcorp Alaska,LLf. Date:9/27/2016 13. ND rod stripper, install surface equipment onto well and test to 1,500 psi. 14. RD Moncla#401 WO Rig. 15. Roll up Rotoflex pumping unit, recouple, and remove LOTO on motor. 16. Return to production with same surface safety system as previously installed. 17. Replace IA x OA pressure gauge if removed (7-5/8" x 10-3/4"). Attachments: 1. Actual Schematic 2. Proposed Schematic Soldotna Creek Unit 0 1110 Well SCU 31-08 . 14 ACTUAL SCHEMATIC CTDp181 099 letion Ran:2/27/2013 Ilileoro Alaska,SIC API: 50-133-20344-00 CASING DETAIL RKB= 19.50'/�GL=128'AMS L Size Wt Grade Conn ID Top Btm A 1 r/{1 20" 94# H-40 - 19.124" Surface 72' 10-3/4" _ 40.5# K-55 10.050" Surface 3,354' 7-5/8" 33.7# S-95 - 6.765" Surface 7-5/8" 26.4# N-80 - 6.969" B — 20" 7-5/8" 29.7# N-80 - 6.875" 10,452' 5-1/2" 20# N-80 - 4.778" 10,246' 10,902' TUBING DETAIL I 0— 2-7/8" 6.5# L-80 EUE 8RD 2.441" Surface 10,417' 10-3/4" Suspected Rod Part `° $ Liner Top JEWELRY DETAIL 9/27/2016 10,246' No. Depth Length ID OD Item C 1 19.5' 0.66 2.441 Tubing Hanger 2 2,501' 2.32 2.430 4.00 Chemical Injection Mandrel 3 10,417' 0.65 _ 2.441 3.50 Seating Nipple D — G2 4 10,418' 2.32 2.441 4.50 Tubing Anchor(Set 19k tension) 5 10,421' 0.35 2.992 3.50 Crossover XO 2-7/8"Box 8rd x3 1/2"Pin 8rd E 6 10,421' 4.00 2.992 3.50 Slotted Sub j ' 7 10,425' 63.43 _ 2.992 3.50 2 jts 3-1/2"Tubing 1 ! 3 8 10,489' 0.44 2.992 3.80 Bull Plug _ 4 -5 F 6 H1 ROD DETAIL A II 7 7-5/8" No. Depth Length OD Item 8 A 15' 40' 1-1/2" Polished Rod,30'in well H2/3 B 55' 450' 1" 1"x 25'EL Sucker rods w/ 3 XL guides per rod 505' 2,825' 1" 1"x 25'EL Sucker rods w/"No"XL guides per rod 3,330' 3,550' 7/8" 7/8"x 25'EL Sucker rods w/ 3 XL guides per rod 6,880' 750' 3/4" 3/4"x 25'EL Sucker rods w/ 3 XL guides per rod H4/5 7,630' 250' 3/4" 3/4"x 25'EL Sucker rods w/ 12 XL guides per rod 7,880' 2,175' 3/4" 3/4"x 25'EL Sucker rods w/ 3 XL guides per rod H6 C 10,055' 300' 1-1/2" 1-1/2"x 25'K Bars(weight bars) Tag Fill @ 10,613' D 10,355' 32.5' 1" 1"x 30"Stabilizer Bar w/'/"Pins Sand&Perf Debris E 10,388' _ 42' 1-3/4" 1-3/4"x 42'Insert Pump,RHBC Pump#3332 w/PA Ring 2/26/13 Ef1f1f1f1fy H8 80 PA Ring,Sand Seal,2-1/2"x 1-3/4"x 36"x 36-1/2"x 37" ,f1f1f1f1f1f1. RH BC(NEW 3/28/15) 14::41::::::41::" F 10,430' 16' 1-1/2" Dip Tube 1.1.1.1.1.1. •rrrrr1r1• •r•r•r•r•r•r 1.1.1.1.1•;•_ H8 'r•r•r•r•r•r• };.v.v.ti f}} . fl}}}}}}}}}}::._ ftiftiftif :r:Fi}:}ti}:}•= H8 .ftiflfSfSftijl. opy::::::::::: 1.1.1.1.1.1• ef•r•r.r•r•r 1.1.1.1.1• :r•r•r.r•r•r er3$7ftifb;;.v.. H8 :Jtifti'~r111r1; e}.e.e.rb}.}}; •r1.1.1.1.1.1• •r•r•r•r•r :r1r~r~r~r:r .r1 f1r1r1r1 f— H10 :f}f}f}j:f:f}; esti fti.,ti fti;:::. '071.1.1.1.1.1. •C1r1f1:1f1f1: :r•r•r•r•r•r•• 1.1.1.1.1.1. :6161r16tirtirl PERFORATION DETAIL ON NEXT PAGE i}}ti}}}ifti}i; :}}r;f:'yo}:; ::::::::•1.1 NOTE:The Surface Casing annulus was used to down squeeze the 5-1/2" liner lap during the 1986 workover of this well. PBTD=10,854'MD;10,734'TVD TD=10,904'MD;10,783'ND MAX HOLE ANGLE=17 deg Downhole Revised:06/20/14 Updated by JEK 9/27/16 • • ell SCU 31-08 Soldotna Creek Unit • ACTUAL SCHEMATIC Wpn:2/27/2013 PTD: 181 099 Hileoro Alaska.LLC API: 50-133-20344-00 PERFORATION HISTORY(DIL) Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt spf Comments Date G1 10,374' 10,384' 10,267' 10,277' 10' 6 2"Pi HC,60 deg 4/5/2001 H1 10,442' 10,448 10,333' 10,339' 6' 6 3-3/8"HC 60 deg 2/27/13 H1 10,445' 10,451' 10,336' 10,342' 6' 6 2"PJ HC,60 deg 4/5/2001 H2/3 10,467' 10,515' 10,357' 10,404' 48' 6 2"PJ HC,60 deg 4/5/2001 H2/3 10,469' 10,514' 10,359' 10,403' 45' 6 3-3/8"HC 60 deg 2/27/13 H4/5 10,532' 10,580' 10,420' 10,467' 48' 6 3-3/8"HC 60 deg 2/27/13 H5 10,534' 10,565' 10,422' 10,452' 31' 6 1-11/16"HC 11/5/1999 10,565' 10,580' 10,452' 10,467' 15' 4 1-11/16"HC 2/23/1998 H6 10,596' 10,610' 10,482' 10,496' 14' 4 2-1/8"Enerjet 6/8/1995 H8 10,616' 10,634' 10,502' 10,519' 18' 4 2-18/"DA Slimkone 5/10/1983 6 3-3/8"Baker TCG 8/4/1986 H8 10,664' 10,672' 10,549' 10,556' 8' 4 2-18/"DA Slimkone 5/10/1983 6 3-3/8"Baker TCG 8/4/1986 H8 10,695' 10,703' 10,579' 10,587' 8' 4 2-18/"DA Slimkone 5/10/1983 4 3-3/8"Baker TCG 8/4/1986 H8 10,706' 10,710' 10,590' 10,593' 4' 4 2-18/"DA Slimkone 5/10/1983 6 3-3/8"Baker TCG 8/4/1986 H10 10,726' 10,732' 10,609' 10,615' 6' 4 2-18/"DA Slimkone 10/7/1982 6 3-3/8"Baker TCG 8/4/1986 Downhole Revised:06/20/14 Updated by JEK 9/27/16 SoldotnaWellSCU Creek3108 Unit PROPOSED SCHEMATIC PTD p181-099 letion n:2/27/2013 Hacara Alaska.LLC API: 50-133-20344-00 CASING DETAIL RKB= 19.50'/GL=128'AMSL Size Wt Grade Conn ID Top Btm A ;1 i; 1 20" 94# H-40 19.124" Surface 72' 10-3/4" 40.5# K-55 10.050" Surface 3,354' 7-5/8" 33.7# S-95 6.765" Surface 7-5/8" 26.4# N-80 - 6.969" B 20" 7-5/8" 29.7# N-80 - 6.875" 10,452' 5-1/2" 20# N-80 - 4.778" 10,246' 10,902' TUBING DETAIL 2 2-7/8" 6.5# L-80 EUE 8RD 2.441" Surface 10,417' > 10-3/4" S g Liner Top JEWELRY DETAIL C 10,246' No. Depth Length ID OD Item 1 19.5' 0.66 2.441 Tubing Hanger 2 2,501' 2.32 2.430 4.00 Chemical Injection Mandrel 3 10,417' 0.65 2.441 3.50 Seating Nipple - G2 4 10,418' 2.32 2.441 4.50 Tubing Anchor(Set 19k tension) D 5 10,421' 0.35 2.992 3.50 Crossover XO 2-7/8"Box 8rd x3-1/2"Pin 8rd E I, 6 10,421' 4.00 2.992 3.50 Slotted Sub ...i. 10,425' 63.43 2.992 3.50 2 jts 3-1/2"Tubing 1., 3 8 10,489' 0.44 2.992 3.80 Bull Plug 4 Jai 5 Fr6 H1 ROD DETAIL L 7 7-5/8" No. Depth Length OD Item gm 8 A 15' 40' 1-1/2" Polished Rod,30'in well H2/3 B 55' 450' 1" 1"x 25'EL Sucker rods w/ 3 XL guides per rod 505' 2,825' 1" 1"x 25'EL Sucker rods w/"No"XL guides per rod 3,330' 3,550' 7/8" 7/8"x 25'EL Sucker rods w/ 3 XL guides per rod 6,880' 750' 3/4" 3/4"x 25'EL Sucker rods w/ 3 XL guides per rod H4/5 7,630' 250' 3/4" 3/4"x 25'EL Sucker rods w/ 12 XL guides per rod 7,880' 2,175' 3/4" 3/4"x 25'EL Sucker rods w/ 3 XL guides per rod C 10,055' 300' 1-1/2" 1-1/2"x 25'K Bars(weight bars) Tag Fill @ 10,613' H6 D 10,355' 32.5' 1" 1"x 30"Stabilizer Bar w/%"Pins Sand&Perf Debris E 10,388' 42' 1-3/4" 1-3/4"x 42'Insert Pump,RHBC Pump#3332 w/PA Ring 2/26/13 ';f}f}f;•ftif;•ft H8 80 PA Ring,Sand Seal,2-1/2"x 1-3/4"x 36"x 36-1/2"x 37" ti•ti•ti•ti•;; rr•f•f• •f•r ti•ti•ti•ti•ti•1• RHBC(NEW) rr•r•r•f•f•r•. ~':';'~';•'" F 10,430' 16' 1-1/2" Dip Tube rr•r•r•r•r•r•� *,::::::::::::::41 ti•ti•ti•ti•ti.S. •r•r•r•f•f•fy' H8 pti1 :ti▪:::PtiPP: .ftiftiftiftifti9:: •f•r.r•r•r.r H 8 r ftirtir.e•e•4— rrtir'%f:f1ftif::: v."::::::::::::::::.: ti.ti.1.1.1.ti• •r'r.f'r'r'3-t ti•ti•ti•ti•ti• rr•f•f•l•r•f� ti.ti.ti.ti.1.,� H8 rf•f•f•r•r•fti� rf~r~r~l1ftiryl !RiZIti jti jti fti' ti•ti•ti•ti•ti•U• :too.f•f•r}. ti.'L.ti.ti.1••� r�.r r.r.r•r rrtir;fti ftirtirl H10 ::::::.1.111:▪:::::: r f}f}f}.46.12: rr:r:▪f1▪fLftifti▪: •iti11▪r1▪f1▪f'4f'L▪i rr•r•r•r•r•r.. ti.1.1.1.1.L, :•%•%•%•%•%•%, PERFORATION DETAIL ON NEXT PAGE r�•r•r•r•r•r•. rrtiftifL'r:11::: .ro.p'pr• ci:r.r.{r.r.' NOTE:The Surface Casing annulus was used to down squeeze the 5 1/2" liner lap during the 1986 workover of this well. PBTD=10,854'MD;10,734'ND TD=10,904'MD;10,783'ND MAX HOLE ANGLE=17 deg Downhole Revised:06/20/14 Updated by JEK 9/27/16 Soldotna Creek Unit Well SCU 31-08 • II PROPOSED SCHEMATI WelletionRan:2/27/2013 PTD: 181-099 Hileoro Alaska.LLC API: 50-133-20344-00 PERFORATION HISTORY(DIL) Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt spf Comments Date G1 10,374' 10,384' 10,267' 10,277' 10' 6 2"PJ HC,60 deg 4/5/2001 H1 10,442' 10,448 10,333' 10,339' 6' 6 3-3/8"HC 60 deg 2/27/13 H1 10,445' 10,451' 10,336' 10,342' 6' 6 2"PJ HC,60 deg 4/5/2001 H2/3 10,467' 10,515' 10,357' 10,404' 48' 6 2"PJ HC,60 deg 4/5/2001 H2/3 10,469' 10,514' 10,359' 10,403' 45' 6 3-3/8"HC 60 deg 2/27/13 H4/5 10,532' 10,580' 10,420' 10,467' 48' 6 3-3/8"HC 60 deg 2/27/13 H5 10,534' 10,565' 10,422' 10,452' 31' 6 1-11/16"HC 11/5/1999 10,565' 10,580' 10,452' 10,467' 15' 4 1-11/16"HC 2/23/1998 H6 10,596' 10,610' 10,482' 10,496' 14' 4 2-1/8"Enerjet 6/8/1995 H8 10,616' 10,634' 10,502' 10,519' 18' 4 2-18/"DA Slimkone 5/10/1983 6 3-3/8"Baker TCG 8/4/1986 H8 10,664' 10,672' 10,549' 10,556' 8' 4 2-18/"DA Slimkone 5/10/1983 6 3-3/8"Baker TCG 8/4/1986 H8 10,695' 10,703' 10,579' 10,587' 8' 4 2-18/"DA Slimkone 5/10/1983 4 3-3/8"Baker TCG 8/4/1986 H8 10,706' 10,710' 10,590' 10,593' 4' 4 2-18/"DA Slimkone 5/10/1983 6 3-3/8"Baker TCG 8/4/1986 H10 10,726' 10,732' 10,609' 10,615' 6' 4 _ 2-18/"DA Slimkone _ 10/7/1982 6 3-3/8"Baker TCG 8/4/1986 Downhole Revised:06/20/14 Updated by JEK 9/27/16 STATE OF ALASKA RECEIVED AL ,:A OIL AND GAS CONSERVATION COMt_ MON APR,2 41015 • REPORT OF SUNDRY WELL OPERATIONS 1\ (•i(a`+45r L. 1.Operations Abandon U Repair Well LJ Plug Perforations LJ Perforate LJ Other lir Performed: Alter Casing ❑ Pull Tubing❑ Stimulate-Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat.Shutdown❑ Stimulate-Other ❑ Re-enter Suspended Well❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development 2 Exploratory ❑ 181-099 3.Address: 3800 Centerpoint Drive,Suite 100 Stratigraphic Service ❑ 6.API Number: Anchorage,Alaska 99504 50-133-20344-00 7.Property Designation(Lease Number): 8.Well Name and Number: FEDA028997 Soldotna Creek Unit(SCU)31-08 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Swanson River Field/Hemlock Oil 11.Present Well Condition Summary: Total Depth measured 10,904 feet Plugs measured N/A feet true vertical 10,783 feet Junk measured 10,627(fill) feet Effective Depth measured 10,854 feet Packer measured 10,421 feet true vertical 10,734 feet true vertical 10,313 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 40' 20" 72' 72' Surface 3,354' 10-3/4" 3,354' 3,354' 3,130 psi 1,580 psi Intermediate Production 10,452' 7-5/8" 10,452' 10,343' 6,020 psi 3,400 psi Liner 656' 5-1/2" 10,902' 10,781' 9,190 psi 8,830 psi Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic SCANNED APR 3 0 'LUIS Tubing(size,grade,measured and true vertical depth) 2-7/8" 6.4#L-80 10,564'MD 10,451'TVD 10,421'MD Packers and SSSV(type,measured and true vertical depth) Anchor 10,313'ND N/A N/A 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 0 0 Subsequent to operation: 35 2 75 190 195 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run N/A Exploratory❑ Development❑r Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil E Gas ❑ WDSPL❑ GSTOR ❑ WINJ p WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 315-121 Contact Joe Kaiser Email jkaiserct'D.hilcorD.com Printed Name Joe Kaiser Title Operations Engineer/ Thf Signature 2'' Phone 907-777-8393 Date V�Z`7/1J ----- 7e �_��. . �� RBDMS a� APR 2 8 2015 Form 10-404 Revised 10/2012 � Submit Original Only , 0' 0 Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date SCU 31-08 50-133-20344-00 181-099 3/27/15 3/28/15 Daily Operations: 03/27/2015-Friday Hold safety meeting with Rig crew and reviewed PTW and JSA. Unfold and lay out pit liner 110 x 120 ft. MIRU Moncla 40_1,__ Build berm around rig with timbers. Hot oil arrives on location. Pick up string. Good indication no parted rods. Saw 24K lbs on weight indicator indicating our string weight. Attempt at slowly working pump out of seat by jarring. 13 attempts at unseating pump. 45K average during 13 attempts at unseating pump. Weight indicator broke free at 35k lbs. Pump off seat. Well started on a vacuum. Picked up string 30 feet. Online with hot oil at.6 bbls min and 175 degree water. No indication of pressure building. Walk pump up to 2 bbls/min at 175 degree F. 30 bbl volume pumped to clean rods of any parraffin and oil. Saw applied pump pressure increase to 210 psi at surface after 20 bbl volume away. Crew attempt at rigging up tongs. Tongs not working. Decision was made to use hand tongs. Half way through noticed rods coming back dirty. Stopped pulling rods and pumped 20 bbls of water at 175 degrees F. Continue to POOH. Pump at surface and laid down. Crews remove Weatherford acquisition tool. Steve Meyers with Weatherford contacted to pick up tool. Location secure. Wellhead valves double isolated and physically checked my WSM. Crews off location. 03/28/2015-Saturday Hold safety meeting and discuss JSA. Picked up new_pump_Found previous used dip tube to be plugged up. Moncla crew using hot pressure washer to clean tube perforations. Performed bucket test on pump assembly. RIH with pump and new rods. Installing polished rod. Stack string weight on pump seals.Good indication pump set in place. Picked up and slacked off abruptly to ensure all seals are engaged. Pollard hot oil on line down tubing. Fill tubing with 30 bbls of lease water. Hot oil pressured up to 250 psi. Bleed back to hot oil and shut in wing valve. Picked up pump 42 inches off bottom. Marked polished rod with chalk to ensure driller doesn't bottom out pump. Install pressure gauge on flow line.Stroke pump 5 times. Tubing pressure increased 200 psi each time. 700 psi on tubing via rod pump. 5 minute test. No indication of bleed off. Bleed of tubing. Changed packoff seals in rod head. Measurement from Rotaflex cement base to top of rod 148 inches. Wellhead and rod work completed. Rig down Moncla 401. Demobe timbers and folded up herculite and stacked out on location with the Moncla 401. Built containment with 12"x 12"timbers for rig while on standby at Swanson. Location secure and clean.Crews off location 1800 hrs. Soldotna Creek Unit Well SCU 31-08 . H ACTUAL SCHEMATIC Completion n9 n:2/27/2013 PTD: 181-0 Hilcoro Alaska.LLC API: 50-133-20344-00 CASING DETAIL RKB= 19.50'/GL=128'AMSL U Size Wt Grade Conn ID Top Btm I 1 20" 94# H-40 - 19.124" Surface 72' �J 10-3/4" 40.5# K-55 - 10.050" Surface _ 3,354' 7-5/8" 33.7# S-95 - 6.765" Surface 20" 7-5/8" 26.4# N-80 - 6.969" 7-5/8" 29.7# N-80 - 6.875" 10,452' 5-1/2" 20# N-80 - 4.778" 10,246' 10,902' TUBING DETAIL 2 2-7/8" 6.5# L-80 EUE 8RD 2.441" Surface 10,417' 10-3/4" S E Liner Top JEWELRY DETAIL C 10,246' No. Depth Length ID OD Item 1 19.5' 0.66 2.441 Tubing Hanger 2 2,501' 2.32 2.430 4.00 Chemical Injection Mandrel 3 10,417' 0.65 2.441 3.50 Seating Nipple D -_ - G2 4 10,418' 2.32 2.441 4.50 Tubing Anchor(Set 19k tension) 5 10,421' 0.35 2.992 3.50 Crossover XO 2-7/8"Box 8rd x3-1/2"Pin 8rd E 6 10,421' 4.00 2.992 3.50 Slotted Sub 7 _ 10,425' 63.43 2.992 3.50 2 jts 3-1/2"Tubing 3 8 10,489' 0.44 2.992 3.80 Bull Plug 4 5 F 6 — H1 ROD DETAIL L 7 7-5/8" No. Depth Length OD Item 8 A 15' 40' 1-1/2" Polished Rod,30'in well H2/3 B 55' 450' 1" 1"x 25'EL Sucker rods w/ 3 XL guides per rod 505' 2,825' 1" 1"x 25'EL Sucker rods w/"No"XL guides per rod 3,330' 3,550' 7/8" 7/8"x 25'EL Sucker rods w/ 3 XL guides per rod 6,880' 750' 3/4" 3/4"x 25'EL Sucker rods w/ 3 XL guides per rod H4/5 7,630' 250' 3/4" 3/4"x 25'EL Sucker rods w/ 12 XL guides per rod 7,880' 2,175' 3/4" 3/4"x 25'EL Sucker rods w/ 3 XL guides per rod H6 C 10,055' 300' 1-1/2" 1-1/2"x 25'K Bars(weight bars) Tag Fill @ 10,613' D 10,355' 32.5' 1" 1"x 30"Stabilizer Bar w/'/,"Pins Sand&Perf Debris E 10,388' 42' 1-3/4" 1-3/4"x 42'Insert Pump,RHBC Pump#3332 w/PA Ring 2/26/13 fyf}f};;f}f± H8 80 PA Ring,Sand Seal,2-1/2"x 1-3/4"x 36"x 36-1/2"x 37" ti•ti•ti•ti•ti• ?'r'r'r'r'r RHBC(NEW 3/28/15) ti'ti"'ti'ti'7 •...•%.r•r•r} "�"'."'� F 10,430' 16' 1-1/2" Dip Tube rtirtirtirtirti�... 'r•r•r•r•r•r•r 'r•r•r•r•r•P:d... H8 0.0.0.0.0.04141. ti•ti•ti•h•1• •r•r•r•r•r•r Tc.:tiftiftifl1 ti.ti•ti.1.ti• • 'r•r•f•r•f•r.r ti.S.ti •` r•r•rr..r•e • •f ♦ • H8 ti•ftiftiftiftiflfl� .71. . 4T 'r.r.f.r.f•f•r 'r•r•r•r•f•r 'r.r.f.r.f.f}r .r;f;r .T.T* •ti•ti•ti•ti•1.ti. r•r•r•r•f•f� ti•ti•ti•ti•ti• 147.1r.pptis H 10 •fa*::ti ftirti f .T.1411•ti•ti• •f1r1rr1f1.yf 'r•r•r•r•f•r•r .ti•ti•ti•ti•ti•ti• .1.1.1.1x1.1: PERFORATION DETAIL ON NEXT PAGE As kompps z s• ti•ti• Al iv a? NOTE:The Surface Casing annulus was used to down squeeze the 10 5-1/2" liner lap during the 1986 workover of this well. PBTD=10,854'MDD;10,734'ND TD=10,904'MD;10,783'ND MAX HOLE ANGLE=17 deg Downhole Revised:06/20/14 Updated by DMA 04/24/15 Soldotna Creek Unit Well SCU 31-08 ACTUAL SCHEMATIC Completion D 19 Ran: Nikoru Alaska.LLC API: 50-133-20344-00 PERFORATION HISTORY(DIL) Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt spf Comments Date G1 10,374' 10,384' 10,267' 10,277' 10' 6 2"PJ HC,60 deg 4/5/2001 H1 10,442' 10,448 10,333' 10,339' 6' 6 3-3/8"HC 60 deg 2/27/13 H1 10,445' 10,451' 10,336' 10,342' 6' 6 2"PJ HC,60 deg 4/5/2001 H2/3 10,467' 10,515' 10,357' 10,404' 48' 6 2"PJ HC,60 deg 4/5/2001 H2/3 10,469' 10,514' 10,359' 10,403' 45' 6 3-3/8"HC 60 deg 2/27/13 H4/5 10,532' 10,580' 10,420' 10,467' 48' 6 3-3/8"HC 60 deg 2/27/13 H5 _ 10,534' 10,565' 10,422' 10,452' 31' 6 1-11/16"HC 11/5/1999 10,565' 10,580' 10,452' 10,467' 15' 4 1-11/16"HC v 2/23/1998 H6 10,596' 10,610' 10,482' 10,496' 14' 4 2-1/8"Enerjet 6/8/1995 H8 10,616' 10,634' 10,502' 10,519' 18' 4 2-18/"DA Slimkone 5/10/1983 6 3-3/8"Baker TCG 8/4/1986 H8 10,664' 10,672' 10,549' 10,556' 8' 4 2-18/"DA Slimkone 5/10/1983 6 3-3/8"Baker TCG _ 8/4/1986 H8 10,695' 10,703' 10,579' 10,587' 8' 4 2-18/"DA Slimkone _ 5/10/1983 4 3-3/8"Baker TCG 8/4/1986 H8 10,706' 10,710' 10,590' 10,593' 4' 4 2-18/"DA Slimkone 5/10/1983 6 3-3/8"Baker TCG 8/4/1986 H10 1.0,726' 10,7.32' 10,609' 10,615' 6' 4 2-18/"DA Slimkone 10/7/1982 6 3-3/8"Baker TCG 8/4/1986 Downhole Revised:06/20/14 Updated by DMA 04/24/15 ....-.....................--..... • v or 74, • w\��\ s7 THE STATE Alaska Oil and Gas ofALAS� Conservation Commission "..___ _ =___:. ,,,,7,...„:„:____,,_.., Ct -.x±___ :- 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 lio wR Main: 907 279 1433 oFALASI(P Fax. 907.276.7542 www aogcc.alaska.gov Joe Kaiser SCAN�1 Operations Engineer 1 1 '3°) Hilcorp Alaska, LLC 3800 Centerpoint Dr., Ste. 1400 Anchorage, AK 99503 Re: Swanson River Field, Hemlock Oil Pool, SCU 31-08 Sundry Number: 315-121 Dear Mr. Kaiser: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, / 1-1- - Cathy P. oerster /J Chair fr- DATED this ,day of March, 2015 Encl. RECEIVED STATE OF ALASKA MAR 0 3 2015 • ALASKA OIL AND GAS CONSERVATION COMMISSION 0 TS 3 /S/ 5 APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 /� 1.Type of Request: Abandon❑ Plug for Redril ❑ Perforate New Pod E Repair Well[ ' ' Change Approved Program❑ Suspend❑ Plug Perforations❑ Perforate❑ Pull Tubing❑ Time Extension❑ Operations Shutdown❑ Re-enter Susp.Wel ❑ Stimulate❑ Alter Casing❑ I Other Rod Repair❑✓ • 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. Hilcorp Alaska,LLC Exploratory ❑ Development n . 181-099 • 3.Address: 3800 Centerpoint Drive,Suite+e9-%yao Stratigraphic ❑ Service ❑ • 6.API Number Anchorage,Alaska 99503 50-133-M44-00 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? CO 123B Soldotna Creek Unit(SCU)31-08 • Will planned perforations require a spacing exception? Yes ❑ No ❑ 9.Property Designation(Lease Number): 10.Field/Pool(s): FEDA028997 • Swanson River Field/Hemlock Oil - 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 10,904 • 10,783 ' 10,854' 10,734' N/A 10,613'(fill) Casing Length Size MD 'ND Burst Collapse Structural - Conductor 40' 20" 72' 72' Surface 3,354' 10-3/4" 3,354' 3,354' 3,130 psi 1,580 psi Intermediate Production 10,452' 7-5/8" 10,452' 10,343' 6,020 psi 3,400 psi Liner 656' 5-1/2" 10,902' 10,781' 9,190 psi 8,830 psi Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic See Attached Schematic 2-7/8" 6.5#L-80 10,147 Packers and SSSV Type: Packers and SSSV MD(t)and ND(ft): N/A;N/A N/A;N/A 12.Attachments: Description Summary of Proposal ❑✓ 13.Well Class after proposed work: - Detailed Operations Program n BOP Sketch n Exploratory n Stratigraphicn Development n Service n 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 03/13/15 Oil ❑✓ . Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Joe Kaiser Phone: 907-777-8393 Email jkaiserehilcorD.com Printed Name Joe Kaiser Title Operations Engineer Signature 1 Phone 907-777-8393 Date -1r /l am COMMISSION USE ONLY Conditi ns of approval: Notify Commission so that a representative may witness Sundry Number: 3t5- 01-\ Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Spacing Exception Required? Yes ❑ No ❑ Subsequent Form Required: /e., — L/0 LI APPROVED BY Approved by: Pag..79414,...‘„-i-sk_i COMMISSIONER THE COMMISSION Date: 3- , 3 ��-K- , 4 -� SubmR Form and RBDMorm-V- (RevisedA10/2012)1 Ofi1&IftaL.for 12 nths from the date of approvAttachmentsiDupliate��7+ � �dG�•r�l(b-,.- T Well Prognosis • Well: SCU 31-08 Hilcorp Alaska,LI) Date:2/26/2015 Well Name: SCU 31-08 API Number: 50-133-20344-00 Current Status: Rod Pump Oil Well Leg: N/A Estimated Start Date: March 13th,2015 Rig: Moncla 401 Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 181-099 First Call Engineer: Joe Kaiser (907)777-8393 (0) (907)952-8897 (M) Second Call Engineer: Stan Porhola (907)777-8412 (0) (907) 331-8228 (M) AFE Number: Current Bottom Hole Pressure: 1,765 psi @ 10,512' MD (Static survey performed on 8/29/12) Maximum Expected BHP: 1,765 psi @ 10,512' MD Max.Allowable Surface Pressure: —0 psi (Based on actual reservoir conditions and min water cut of 95% (0.435psi/ft) with added Safety Factor of 1,000' TVD of oil cap) Static fluid level @ 5,644' Brief Well Summary Soldotna Creek 31-8 was drilled in 1982 to target H8 and H10 oil reserves in the lower part of the Hemlock formation. Initial production from the H8 and H10 sands exceeded 1100 BOPD. Rapid production decline was attributed to asphaltene and/or paraffin deposits that increased in the wellbore as the GOR increased. These deposits were successfully treated with regular xylene stimulations. In 1986, a rig workover was conducted to replace the production packer and restore casing integrity by squeezing the liner lap. A new gas lift completion was run in 1989 to address a leaking packer and tubing. The upper part of the Hemlock formation (H1-4 sands) and the Tyonek G-Zone were perforated through tubing in 2001. The well went off production in 2002 with a suboptimal gas lift design unable to lift fluid to surface.The well was converted to Rotaflex Rod Pump in February 2013. In June 2014,the'/.",7/8", and 1" rod string was replaced. In December 2014,the well stopped producing from a suspected worn pump or deep rod part. The purpose of this work/sundry is to replace the worn pump or repair parted rods for this Rotaflex Rod Pump well. Notes Regarding Wellbore Condition • Well is currently not producing on rod pump (suspect parted rods near pump). c/ Workover Rig Procedure: 1. Blow-down any pressure on the well and shoot fluid level(echometer)on casing. 2. Roll back Rotoflex pumping unit, uncouple and LOTO motor. 3. MIRU Moncla#401 WO Rig. 4. Nipple up rod stjnner head 'Oa l'O es 5. LD polish rod and pull EL rods to pull pump. Rack back the rods in basket. 6. If parted deep, MU overshot and grapple. Fish parted rods in the 3/4" rods or at the pump. 7. LD and inspect pump, dip tube, memory gages, and all pulled rods. 8. PU existing dip tube. 9. PU new 1-3/4"rod pump. 10. RIH with existing tapered rod string(sinker bars, 3/4",7/8"and 1). Well Prognosis • Well: SCU 31-08 Hilcoru Alaska,LL Date:2/26/2015 11. Space out the rods, install existing polish rod. 12. Test pump to 700 psig for 5 minutes to confirm seated in profile 13. ND rod stripper, install surface equipment onto well and test to 1,500 psi. 14. RD Moncla#401 WO Rig. 15. Roll up Rotoflex pumping unit, recouple,and remove LOTO on motor. 16. Return to production with same surface safety system as previously installed. 17. Replace IA x OA pressure gauge if removed (7-5/8"x 10-3/4"). Attachments: 1. Actual Schematic Soldotna Creek Unit 11 Well SCU 31-08 ACTUAL SCHEMATIC Completion n:2/27/2013 PTD 181 099 Hiker,Alaska.LLC API: 50-133-20344-00 CASING DETAIL RKB= 19.50'/GL=128'AMSL Size Wt Grade Conn ID Top Btm c) 20" 94# H-40 - 19.124" Surface 72' A 1r 10-3/4" 40.5# K-55 10.050" Surface 3,354' 7-5/8" 33.7# 5-95 6.765" Surface 7-5/8" 26.4# N-80 - 6.969" L-- 20 7-5/8" 29.7# N-80 - 6.875" 10,452' 5-1/2" 20# N-80 - 4.778" 10,246' 10,902' TUBING DETAIL 2-7/8" 6.5# L-80 EUE 8RD 2.441" Surface 10,417' 10-3/4" g S Liner Top JEWELRY DETAIL C _ 10,246' No. Depth Length ID OD Item 1 19.5' 0.66 2.441 Tubing Hanger SUSPECTED ROD 2 2,501' 2.32 2.430 4.00 Chemical Injection Mandrel PART NEAR PUMP D 3 10,417' 0.65 2.441 3.50 Seating Nipple G2 4 10,418' 2.32 2.441 4.50 Tubing Anchor(Set 19k tension) E 5 10,421' 0.35 2.992 3.50 Crossover XO 2-7/8"Box 8rd x3-1/2"Pin 8rd 6 10,421' 4.00 2.992 3.50 Slotted Sub 7 10,425' 63.43 2.992 3.50 2 jts 3-1/2"Tubing I. 3 8 10,489' 0.44 2.992 3.80 Bull Plug 4 � 5 F1 6 L G: �,, H1 ROD DETAIL 7-5/8" No. Depth Length OD Item 8 A 15' 40' 1-1/2" Polished Rod,30'in well — H2/3 B 55' 450' 1" 1"x 25'EL Sucker rods w/ 3 XL guides per rod 505' 2,825' 1" 1"x 25'EL Sucker rods w/"No"XL guides per rod 3,330' 3,550' 7/8" 7/8"x 25'EL Sucker rods w/ 3 XL guides per rod 6,880' 750' 3/4" 3/4"x 25'EL Sucker rods w/ 3 XL guides per rod H4/5 7,630' 250' 3/4" 3/4"x 25'EL Sucker rods w/ 12 XL guides per rod 7,880' 2,175' 3/4" 3/4"x 25'EL Sucker rods w/ 3 XL guides per rod H6 C 10,055' 300' 1-1/2" 1-1/2"x 25'K Bars(weight bars) Tag Fill @ 10,613' D 10,355' 32.5' 1" 1"x 30"Stabilizer Bar w/'"Pins Sand&Perf Debris E 10,388' 42' 1-3/4" 1-3/4"x 42'Insert Pump,RHBC Pump#3332 w/PA Ring 2/26/13 .;}f}f}f;f}fes H8 80 PA Ring,Sand Seal,2-1/2"x 1-3/4"x 36"x 36-1/2"x 37" ':ftif5f5fti}i}ti? .rf5f5f5S.. RHBC 'r'r'r41tirtir1r F 10,430' 16' 1-1/2" Dip Tube 5.5.5.5.5.5• 1.4ai•r•r•r•r }:}}}:}} G 10,446' 2.65' 1-1/4" 1-1/4"Memory Gauge(Welded coupling to screen) 'r'Pr'r•r'4 — H8 .5.5.5.5.5• 1 r1:rrf: 11ty r1r1.1r1f1.: H8 rg5:15555 1.: }.r.f.}.r.}.r 14:41.1:41.1.7.". •5.5.5.5.5• f•r•r.r•r5t=== •f;ftif5titif•, H8 14 fti fti f:P f 1:111.•::::::::::.,.-.-. •r5•r•r.5.5.•r•• •r • 1::::::::::::::::P 1?:{f{f11 H 10 r•r•r•r•r•r• 1:::::tif5f51 5f .f}ftiftiftiftif}f .ftiftiftiftiftiftif .:::::Y:::•74:::::*L•5.5.5.5.5. r1r1r1rf1�1r r lFal.J.."r r1.5%.5%.55 r1rr47:CA r f r r•r•r•r•r .1 5•r.5.5. r•r•r .5•r•r•r i •5.5.5.5.5.5• r•r•r•r.r•r•r L PERFORATION DETAIL ON NEXT PAGE •5.5.5.5.5.5. r•r•r•r•r•r•r 1:::::::::::::::N r1r1r1r1r1r1r r1r.1AR M s:r:s7,1;t:�r The Surface Casing annulus was used to down squeeze the �'b \ 5-1/2" liner lap during the 1986 workover of this well. PBTD=10,854'MD;10,734'TVD _ TD=10,904'MD;10,783'TVD MAX HOLE ANGLE=17 deg Downhole Revised:06/20/14 Updated by STP 07/11/14 Soldotna Creek Unit Well SCU 31-08 C letion f ACTUAL SCHEMATIC p 181 099 Ran:2/27/2013 PTD HiIcor,Alaska.LLC API: 50-133-20344-00 PERFORATION HISTORY(DIL) Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt spf Comments Date G1 10,374' 10,384' 10,267' 10,277' 10' 6 2"PJ HC,60 deg 4/5/2001 H1 10,442' 10,448 10,333' 10,339' 6' 6 3-3/8"HC 60 deg 2/27/13 H1 10,445' 10,451' 10,336' 10,342' 6' 6 2"PJ HC,60 deg _ 4/5/2001 H2/3 10,467' 10,515' 10,357' 10,404' 48' 6 2"PJ HC,60 deg 4/5/2001 H2/3 10,469' 10,514' 10,359' 10,403' 45' 6 3-3/8"HC 60 deg _ 2/27/13 H4/5 10,532' 10,580' 10,420' 10,467' 48' 6 3-3/8"HC 60 deg _ 2/27/13 H5 10,534' 10,565' 10,422' 10,452' 31' 6 1-11/16"HC _ 11/5/1999 10,565' 10,580' 10,452' 10,467' 15' 4 1-11/16"HC 2/23/1998 H6 10,596' 10,610' 10,482' 10,496' 14' 4 2-1/8"Enerjet 6/8/1995 H8 10,616' 10,634' 10,502' 10,519' 18' 4 2-18/"DA Slimkone 5/10/1983 6 3-3/8"Baker TCG 8/4/1986 H8 10,664' 10,672' 10,549' 10,556' 8' 4 2-18/"DA Slimkone 5/10/1983 6 3-3/8"Baker TCG _ 8/4/1986 H8 10,695' 10,703' _ 10,579' 10,587' 8' 4 2-18/"DA Slimkone 5/10/1983 4 3-3/8"Baker TCG _ 8/4/1986 H8 10,706' 10,710' 10,590' 10,593' 4' 4 2-18/"DA Slimkone _ 5/10/1983 6 3-3/8"Baker TCG 8/4/1986 H10 10,726' 10,732' 10,609' _ 10,615' 6' 4 2-18/"DA Slimkone 10/7/1982 6 3-3/8"Baker TCG 8/4/1986 Downhole Revised:06/20/14 Updated by STP 07/11/14 Image~l~oj,ect Well History File Cover XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. I O0 l- .~ ~ ~ Well History File Identifier Organizing RESCAH OVERSIZED (Scannable) [] Color items: [] Diskettes, No. [] Maps: [] Grayscale items: [] Poor Quality Originals: [] Other: NOTES: [] Other, No/Type [] Other items scannable by large scanner BY: BEVERLY ROBIN VINCENT SHERYL~WINDY OVERSIZED (Non-Scannable) .~ Logs of various kinds [] Other DATE :(~ 'c:~(~ '~':'~S/ Project Proofing Production Scanning Stage 1 PAGE COUNT FROM SCANNED FILE: BY; Stage 2 (SCANNING I$ COMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION IS REQUIRED ON AN INDIVIDUAL PAGE BASIS DUE TO QUALITY. GRAYSCALE OR COLOR IMAGES) PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: ~ YES ~" NO IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: YES NO Ill IIIIIIIIIII II III ReScanned (individual page [,special at~e¢~tiot~] `scantling cemple~ed) RESCANNEDBY: BEVERLY ROBIN VINCENT SHERYL MARIA WINDY DATE: /si General Notes or Comments about this file: Quality Checked (do.c) 12/10/02Rev3NOTScanned.wpd QEF 'Pk EJ��\\I��i, N 1Ai Ili " c�4,..i_ u — — 333 Wes Scvcnth Averuc ; C ()v"r.RNOR LE.%N PARNEI.i, Ancncrage A'.aska 9950' 35/2 Iain 907.999 .433 Stan Porhola SCANNED JUL 1 6 2014 Operations Engineer Hilcorp Alaska, LLC \ 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Re: Swanson River Field, Hemlock Pool, SCU 31-08 Sundry Number: 314-341 Dear Mr. Porhola: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P. oerster Chair DATED this2 d y of June, 2014. Encl. RECEIVED STATE OF ALASKA MAY 2 ALASKA OIL AND GAS CONSERVATION COMMISSION SMS G� 14 2020 APPLICATION FOR SUNDRY APPROVALS in 4(4/4. 20 AAC 25.280 1.Type of Request: Abandon❑ Plug for Redril 0 Perforate New Pod ❑ Repair Well❑ Change Approved Program❑ Suspend❑ Plug Perforations❑ Perforate❑ Pull Tubing❑ Time Extension❑ Operations Shutdowi❑ Re-enter Susp.Wel 0 Stimulate❑ Atter Casing❑ Other. Rod Pump Repair❑✓ f 2.Operator Name: Hilcorp Alaska,LLC 4.Current Well Class: 5.Permit to Drill Number Exploratory El Development Q • 181-099 - 3.Address: 3800 Centerpoint Drive,Suite 100 Stratigraphic ❑ Service ❑ 6.API Number: Anchorage,Alaska 99503 50-133-20344-00 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? CO 123B • Will planned perforations require a spacing exception? Yes [11No ❑� Sddotna Creek Unit(SCU)31-08 9.Property Designation(Lease Number): 10.Field/Pool(s): FEDA028997 • Swanson River Field/Hemlock Oil • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth ND(ft): Plugs(measured): Junk(measured): 10,904 • 10,783 ' 10,854' 10,734' N/A 10,627'(fill) Casing Length Size MD TVD Burst Collapse Structural Conductor 40' 20" 72' 77 Surface 3,354' 10-3/4" 3,354' 3,354' 3,130 psi 1,580 psi Intermediate Production 10,452' 7-5/8" 10,452' 10,343' 6,020 psi 3,400 psi Liner 656' 5-1/2" 10,902' 10,781' 9,190 psi 8,830 psi Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: 3-1/2" Tubing Grade: 9.2#N-80&9.3#J-55 Tubing MD(ft): 1,013'; See Attached Schematic See Attached Schematic 2-7/8" 6.5#N-80 10,142;10,564' Packers and SSSV Type: Packers and SSSV MD(t)and ND(ft): Baker"DB"Pkr;N/A 10,144'MD-10,045'ND;N/A 12.Attachments: Description Summary of Proposal ❑✓ 13.Well Class after proposed work: Detailed Operations Program n BOP Sketch l Exploratory ❑ Stratigraphic❑ Development n •Service ❑ 14.Estimated Date for 15.Well Status after proposed work: 06/07/14 Commencing Operations: Oil ❑✓ • Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Stan Portiola Phone: 907-777-8412 Email soorhola( hilcorD.coril Printed Name Stan P rhola Title Operations Engineer Signature .�< " �� Date 72Phone 907-777-8412 � COMMISSION USE ONLY / //� Conditions of approval: Notify Commission so that a representative may witness Sundry Number Ll. Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Spacing Exception Required? Yes El No [�► Subsequent Form Required: /6 '--/i y APPROVED BY ''// Approved by: ale" COMMISSIONER THE COMMISSION Date: 6 z , / s-.3a iY /� A e Submit Form and Form 10-403(Revised 10/2 Appr v I t n s d/„+rLmon hs from the date of approval. Attachments in Duplicate R@CMS JUN - 2 21.4A\- au) 5 -3U. y,. 114 Well Prognosis Well: SCU 31-08 Hilcorp Alaska,LL Date:5/28/2014 Well Name: SCU 31-08 API Number: 50-133-20344-00 Current Status: Rod Pump Oil Well Leg: N/A Estimated Start Date: June 7th, 2014 Rig: Moncla 401 / Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 181-099 First Call Engineer: Stan Porhola (907)777-8412 (0) (907) 331-8228 (M) Second Call Engineer: Chad Helgeson (907)777-8405 (0) (907) 229-4824 (M) AFE Number: Current Bottom Hole Pressure: 1,765 psi @ 10,512' MD (Static survey performed on 8/29/12) Maximum Expected BHP: 1,765 psi @ 10,512' MD Max.Allowable Surface Pressure: —0 psi (Based on actual reservoir conditions and min water cut of 95% (0.435psi/ft) with added Safety Factor of 1,000' TVD of oil cap) Static fluid level @ 5,644' Brief Well Summary Soldotna Creek 31-8 was drilled in 1982 to target H8 and H10 oil reserves in the lower part of the Hemlock formation. Initial production from the H8 and H10 sands exceeded 1100 BOPD. Rapid production decline was attributed to asphaltene and/or paraffin deposits that increased in the wellbore as the GOR increased. These deposits were successfully treated with regular xylene stimulations. In 1986,a rig workover was conducted to replace the production packer and restore casing integrity by squeezing the liner lap. A new gas lift completion was run in 1989 to address a leaking packer and tubing. The upper part of the Hemlock formation (H1-4 sands) and the Tyonek G-Zone were perforated through tubing in 2001. The well went off production in 2002 with a suboptimal gas lift design unable to lift fluid to surface.The well was converted to Rotaflex Rod Pump in February 2013. The purpose of this work/sundry is to repair parted rods for this Rotaflex Rod Pump well. V Notes Regarding Wellbore Condition • Well is currently not producing on rod pump (suspect parted rods at+/-4,550' in the 7/8" rods). • Workover Rig Procedure: 1. Blow-down any pressure on the well and shoot fluid level (echometer)on casing. 2. Roll back Rotoflex pumping unit, uncouple and LOTO motor. 3. MIRU Moncla#401 WO Rig. 4. Nipple up rod stripper head. 5. LD polish rod and pull EL rods to parted rod. Rack back the rods in basket. 6. MU overshot and grapple. Fish parted rods at+/-4,550' in the 7/8" rods. 7. LD and inspect pump and dip tube and all pulled rods. 8. PU existing dip tube,add couplsng to diptube. Install memory gauge. 9. PU new 1-3/4"rod pump. ✓ 10. RIH with new tapered rod string(sinker bars, 3/4", 7/8"and 1).• 11. Space out the rods, install new polish rod. 12. ND rod stripper, install surface equipment onto well and test to 3,000 psi. • 14 Well Prognosis Well: SCU 31-08 Hilcorp Alaska,Lb Date:5/28/2014 13. RD Moncla#401 WO Rig. 14. Roll up Rotoflex pumping unit, recouple,and remove LOTO on motor. 15. Return to production with same surface safety system as previously installed. 16. Replace IA x OA pressure gauge if removed (7-5/8"x 10-3/4"). Attachments: 1. Actual Schematic Soldotna Creek Unit Well SCU 31-08 : ACTUAL SCHEMATIC CoDpletion 099 Ran:2/27/2013 HiIron)Alaxka.LLC API: 50-133-20344-00 CASING DETAIL RKB= 19.50'/GL=128'AMSL Size Wt Grade Conn ID Top Btm A ; 1 20" 94# H-40 19.124" Surface 72' 10-3/4" 40.5# K-55 10.050" Surface 3,354' 7-5/8" 33.7# S-95 6.765" Surface 7-5/8" 26.4# N-80 - 6.969" B 20" 7-5/8" 29.7# N-80 - 6.875" 10,452' 5-1/2" 20# N-80 - 4.778" 10,246' 10,902' TUBING DETAIL 2 iit 2-7/8" 6.5# L-80 EUE 8RD 2.441" Surface 10,417' e_ 10-3/4" SUSPECTED ROD PART AT+/-4,550' g g Liner Top JEWELRY DETAIL C 11 10,246' No. Depth Length ID OD Item D 1 19.5' 0.66 2.441 Tubing Hanger 2 2,501' 2.32 2.430 4.00 Chemical Injection Mandrel E .�I. 3 10,417' . 0.65 2.441 3.50 . Seating Nipple F J G2 4 10,418' 2.32 2.441 4.50 Tubing Anchor(Set 19k tension) 5 10,421' 0.35 2.992 3.50 Crossover XO 2-7/8"Box 8rd x3-1/2"Pin 8rd G Iiii 6 10,421' , 4.00 2.992 3.50 , Slotted Sub 7 10,425' 63.43 2.992 3.50 2 jts 3-1/2"Tubing 1 3 8 10,489' 0.44 2.992 3.80 Bull Plug 4 1 5 H 6 .11111 Hi ROD DETAIL 7 7-5/8"ii No. Depth Length OD Item or 8 A 30' 40' 1-1/2" Polished Rod,30'in well H2/3 B 38' 8' 1" 1"x 8'EL Pony Rod 67' 250' 1" 1"x 25'EL Sucker rods w/ 5 XL guides per rod 317' 2,825' 1" 1"x 25'EL Sucker rods w/"No"XL guides per rod 3,142' 3,550' 7/8" 7/8"x 25'EL Sucker rods w/ "No"XL guides per rod H4/5 6,692' 675' 3/4" 3/4"x 25'EL Sucker rods w/ "No"XL guides per rod 7,367' 400' 3/4" 3/4"x 25'EL Sucker rods w/ 12 XL guides per rod H6 7,767' 850' 3/4" 3/4"x 25'EL Sucker rods w/ 4 XL guides per rod Tag Fill @ 10,613' 8,617' 1,425' 3/4" 3/4"x 25'EL Sucker rods w/ "No"XL guides per rod Sand&Perf Debris C 10,042' 300' 1-1/2" 1-1/2"x 25'K Bars(weight bars) 2/26/13 5fyr+'+f+'� '?{?{?;{?? H8 D 10,342' 30' 1" 1"x 30"Stabilizer Bar w/'/,"Pins(between K Bars) 'r•r•r.r. .1.it �%;. �c. E 10,372' 1' _ BrowningOn/Off Tool,J-Latch R hand release(Box X Pin) 'f•r•r•f•f•f•r 1.1.1.1.1.1. 'f.r•r.r•r•r•r 'f:}.r}}:}}}}} F 10,373' 2.5' 1" 1"x 30"Stabilizer Bar w/3/4"Pins .1.•••1.4.1.1. _ f.f.r•f•f•r•. •.1.1.1.1.1. r.r•r•r•f•r* H8 G 10,376' 42' 1-3/4" 1-3/4"x 42'Insert Pump,RHBC Pump#3332 w PA Ring . .1.1.1.1.5' ?{?{?{?{?ti• 80 PA Ring,Sand Seal,2-1/2"x 1-3/4"x 36"x 36-1/2"x 37" 'r•f•f.r•f•r•r 4141:rtir~rtir RHBC .1.1.1.1.1.1 •f•f•f•r•r 1::::::::::::::P., H8 H 10,418' 13' 1-1/2" Dip Tube .:;ftif}ftiftiflf 1••.•1.1.1•{• r.r.f.r.r.r•r 1tf}:4141}f1; .ftif T.T. }fyr :~tif}ti ftif• .f:ff}f}ff:f}f}f Ta.1}f}f:f}; ytir1.1.1 .er H10 r:Y*1' Pr T.14141:::::::* fti4T::::?ti?ti: ftif??:,•ftif ?tirtir141:::? rtir:PP: ff r•r•r.r•f•r•f .1.1.1.1.1.1• :::::PP:414. PERFORATION DETAIL ON NEXT PAGE '?•f•r•r•r•r•r ---- ti•1•ti.1.•ti.ti. 'r•r•r•r•r•r•r 141.1.ti1:ftiftif .?•f•f1f.rlflr 1.1.1.1.1.1• NOTE:The Surface Casing annulus was used to down squeeze the A.:.A.i \ 5-1/2" liner lap during the 1986 workover of this well. PBTD=10,854'MD;10,734'ND TD=10,904'MD;10,783'ND MAX HOLE ANGLE=17 deg Downhole Revised:05/20/14 Updated by STP 05/28/14 Soldotna Creek Unit Well SCU 31-08 ,:u ACTUAL SCHEMATIC pn:2/27/2013 PTD: 181 099 Hilcora Alaska.LLC API: 50-133-20344-00 PERFORATION HISTORY(DIL) Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt spf Comments Date G1 10,374' 10,384' 10,267' 10,277' 10' 6 2"PJ HC,60 deg 4/5/2001 H1 _ 10,442' 10,448 10,333' 10,339' 6' 6 3-3/8"HC 60 deg 2/27/13 H1 _ 10,445' 10,451' 10,336' 10,342' 6' 6 2"PJ HC,60 deg 4/5/2001 H2/3 _ 10,467' 10,515' 10,357' 10,404' 48' 6 2"PJ HC,60 deg 4/5/2001 H2/3 _ 10,469' _ 10,514' 10,359' 10,403' 45' 6 3-3/8"HC 60 deg 2/27/13 H4/5 _ 10,532' 10,580' 10,420' 10,467' 48' 6 3-3/8"HC 60 deg 2/27/13 H5 10,534' 10,565' 10,422' 10,452' 31' 6 1-11/16"HC 11/5/1999 10,565' _ 10,580' 10,452' 10,467' 15' 4 1-11/16"HC 2/23/1998 H6 10,596' 10,610' 10,482' 10,496' 14' 4 2-1/8"Enerjet 6/8/1995 H8 10,616' 10,634' 10,502' 10,519' 18' 4 2-18/"DA Slimkone 5/10/1983 6 3-3/8"Baker TCG 8/4/1986 H8 10,664' 10,672' 10,549' 10,556' 8' 4 2-18/"DA Slimkone 5/10/1983 6 3-3/8"Baker TCG 8/4/1986 H8 10,695' 10,703' 10,579' 10,587' 8' 4 2-18/"DA Slimkone 5/10/1983 4 3-3/8"Baker TCG 8/4/1986 H8 _ 10,706' 10,710' 10,590' 10,593' 4' 4 2-18/"DA Slimkone 5/10/1983 6 3-3/8"Baker TCG 8/4/1986 H10 10,726' 10,732' 10,609' 10,615' 6' 4 2-18/"DA Slimkone 10/7/1982 6 3-3/8"Baker TCG 8/4/1986 Downhole Revised:05/20/14 Updated by STP 05/28/14 E REVS STATE OF ALASKA • �r1 �� .� • AL OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS AOGCC 1. Operations Abandon U Repair Well U Plug Perforations U Perforate L] • Other U Install Rod Pump, RTP • Performed: Alter Casing ❑ Pull Tubing 0 . Stimulate - Frac ❑ Waiver ❑ Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Stimulate - Other ❑ Re -enter Suspended Well ❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: Hilcorp Alaska, LLC Development 0 • Exploratory ❑ 181 -099 3. Address: 3800 Centerpoint Drive, Suite 100 Stratigraphic ❑ Service ❑ 6. API Number: Anchorage, Alaska 99504 50- 133 - 20344 -00 7. Property Designation (Lease Number): 8. Well Name and Number: FEDA028997 Soldotna Creek Unit (SCU) 31 -08 + 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): N/A Swanson River Field / Hemlock Oil ' 11. Present Well Condition Summary: • 1 Total Depth measured 10,904 feet Plugs measured N/A feet true vertical 10,783 feet Junk measured 10,627 (fill) feet Effective Depth measured 10,854 feet Packer measured 10,421 feet true vertical 10,734 feet true vertical 10,313 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 40' 20" 72' 72' Surface 3,354' 10 -3/4" 3,354' 3,354' 3,130 psi 1,580 psi Intermediate Production 10,452' 7 -5/8" 10,452' 10,343' 6,020 psi 3,400 psi Liner 656' 5 -1/2" 10,902' 10,781' 9,190 psi 8,830 psi Perforation depth Measured depth See Attached Schematic SCANNED MAY 1 5 ZO True Vertical depth See Attached Schematic Tubing (size, grade, measured and true vertical depth) 2 -7/8" 6.4# L -80 10,564' MD 10,451' TVD 10,421' MD Packers and SSSV (type, measured and true vertical depth) Anchor 10,313' TVD ' ` " ' ' 1v /A` N/A 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 0 150 Subsequent to operation: 44 80 19 175 175 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run N/A Exploratory ❑ Development E Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil 151 ' Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 313 -085 Contact Chad Helgeson Email cheloeson@hilcoro.com Printed Name Chad Helgeson Title Operations Manager Signature —7/41/13 Phone 907 - 777 -8405 Date � /t 3 Form 10 -404 Revised 10/2012 RBDMS MAY 10101 Submit Original Only • • Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date SCU 31 -08 50- 133 - 20344 -00 181 -099 2/18/13 3/1/13 Da Ope y ; ` J �s -i: " ' '-': !,•>. - z 9 ; 7 y .; ° p:: S,'` A,� , . A :' z Yec,:. - ` - a "" Y '«v ^ �E `• "": ,.: r.:' ' , 4/OI�V[RCl.4{l ,4+. x . .. `' s ` :.... �- � . +... . Y',.. d' 02/18/2013 - Monday MIRU Williams WOR and Installed Winterization Kits. 02/19/2013 - Tuesday Finished final RU, MIRU SL. RIH w /px plug and prong and set in xn nipple. Pumped 360 bbls of PW and could not break circulation. RIH and pulled prong and plug. PU a 2.79" GR and RIH. Located x nipple at 10,046' wlm. PU a 2.831" px plug and RIH, set plug and prong in x nipple at 10,046' wlm. Started pumping down tbg and broke circulaton at report time. 02/20/2013 - Wednesday Continued circulating down tbg, pumped 450 bbls to clean well. SI csg and tested. Started pumping in at 700 psi. RIH w /dummy to 10,068' wlm. Could not locate GLM. POOH. RIH w /2" JDC to 10,037' wlm, POOH w /px prong. Well on a vacuum. RIH w /2" GS to PX plug at 10,038' wlm. Jar up to 1,900 psi and could not pull. Sheared off and POOH. Cut 150' of , wire and reheaded. RIH and latched plug. Jarred and could not pull plug. POOH and RDMO WL. Set BPV, ND tree and NU 11" BOP stack. Testing BOPE at report time. 02/21/2013 - Thursday Tested BOPE per AOGCC /BLM - 250 psi low, 3,000 psi high - Witness waived by Jim Regg, AOGCC 2/19/19. MIRU SL, RIH w /3" GS pulling tool and tag at 10,035' wlm. Latched plug and jarred. Could not pull plug. 'Sheared off and POOH. RDMO SL. MIRU EL, RIH w /ccl, set down at 10,064' wlm. Could not work free. POOH. PU 2.5" LIB and RIH. Tag at 10,064' WLM. POOH. LIB showed the top of the fishing neck on plug. RDMO EL. MIRU braided Line. RIH w /GS pulling tool and and Iatchei • plug. Jar on plug and pulled off at 4000 psi. POOH. RIH w/ heavier GS pulling tool at report time. 02/22/2013 - Friday PU on string to 100,000# and released hanger (string weight 94,000 #). PU to 110,000 #, slacked off and worked string 10 time and pulled free weighing 88,000 #. L/D 3 -1/2" tbg, 2 GVM, X nipple and 10' locator seal. 02/23/2013 - Saturday PU Jars, 4 DC, Boot Basket and Packer Shoe. TIH and tag packer @ 10,127'. Started pumping 2 BPM, milled on packer for 5 hrs and packer fell. Circulated bottoms up and TOOH. ID BHA. 02/24/2013 - Sunday PU Grapple, oil jars, acc jars, bumper jars and spear, tag fish @ 10,190'. Latched packer and TOOH w /packer, XN nipple and 13 jts of 2 -7/8 ". LD BHA and fish. 02/25/2013 - Monday PU BP and test packer, RIH, set BP and set packer in 5.5" liner at 10,330'. Broke circulation and pressured up to 500 psi. Pressured up to 750 psi and started pumping in at 2 pbm. Released packer and BP. Tried to reset BP and test packer but keep slipping. TOOH. The Test packer had the bottom rubber elements torn off with metal cuttings around it. PU 7 -5/8" test packer and TIH to 10,120', Set test packer and filled hole. Tested to 2,000 psi for 30 mins (charted). TOOH at report time. 02/26/2013 - Tuesday L/D test packer. MIRU SL. RIH w/ 5.5" centralizer and 4.5" magnet to 10,230' wlm. POOH w/ metal shavings. RIH to same and POOH w/ metal shavings. RIH w/ Bow spring cent, w/ 3.80" swedge, w/ 3.75" magnet and tag @ 10,613'. POOH w/ packer debris and 2 small chunks of metal. RIH w/ same and tag 10,613' wlm, POOH w/ metal debris. RIH w/ same and tag 10,613' wlm, POOH w /debris. RIH w/ same and tag 10,613' wlm, POOH w/ metal debris. RIH w/ 3.80" swedge and 3" drivedown bailer and tag @ 10,613' wlm, worked tool and POOH. Bailer was empty. RIH w/ 3.75" magnet to 10,613' wlm. POOH w/ 1 chunk of metal. RIH w/ same to 10,613' wlm. POOH w/ a small amount of metal shavings. RDMO SL. MIRU EL, RIH w/ 3 20' 3 -3/8" HC gun. Tag at 10,611' and log up to 10,250'. Tied -in log and ran back down to 10,560' WLM. Perf from 10,560'- 10,580'. POOH. PU 28' gun and RIH to 10,532' and Perf from 10,532'- 10,560'. POOH. 02/27/2013- Wednesday Perf H2/3 from 10,469'- 10,514', Perf H1 10,448'- 10,442'. RDMO EL. TIH with BHA and 327 jts of 2 -7/8" tbg. Set Anchor at 10,418'. Landed hanger with 19,000# in tension. Set BPV and ND BOP's. 02/28/2013 - Thursday NU PT, Pulled BPV, Dropped test plug and pressure tested tbg to 500psi. Tested good. MIRU SL. RIH w /2" JDC to 10,417' and latched plug. POOH w /plug. RDMO SL. PU pump and rods and TIH. Seated pump and tested to 300 psi. Spaced out rods and hung off. Started RD Williams WOR. 03/01 /2013 - Friday Finished rigging WOR and winterization kit down. Moved to new location. Turned over to production. • • • Soldotna Creek Unit Well: SCU 31 -08 SCHEMATIC Completed: 10/19/82 Hilcorp Alaska, LLC PTD: 181 -099 API: 50- 133 - 20344 -00 RKB: 19.50' CASING DETAIL All Measurements are RKB to Top of Equip. ent Size WT Grade Top Btm A 20" Surface 72' I11 1 10 -3/4" 40.5 K -55 Surface 3,354' 33.7 595 Surface 20" B 7 -5/8" 26.4 N80 III 29.7 10,452' 5 -1/2" 20 N80 10,246' 10,902' TUBING DETAIL I I 2 -7/8" I 6.4 I L80 EUE I 0 I 10,417' I 71 2 10 -3/4'4 IT ■ II JEWELRY DETAIL 0 1 # Depth' Length' ID" OD" Description III 1 20' 0.66 2.441 Tubing Hanger I 2 2,504' 2.32 2.43 4 Chemical Injection Mandrel D 3 10,418' 0.65 2.441 3.5 Seating Nipple ICI 4 10,421' 2.32 2.441 4.5 Tubing Anchor P 5 10,421' 0.5 2.992 3.5 Crossover XO 2 -7/8" Box 8rd x3 -1/2" Pin 8rd E ICI 6 10,421' 10 2.992 3.5 Slotted Sub, 3 -1/2" Tubing L _i_ 7 10,489' 0.44 2.992 3.8 Bull Plug G1 ROD DETAIL 3 ►:_ 4 # Depth Length OD Description 7 -5/8" I I A 30' 40' 1 -1/2" Polished Rod, 30' in well 5 B 38' 8' 1" 1" x 8' EL Pony Rod GF 67' 250' 1" 1" x 25' EL Sucker rods w/ 5 XL guides per rod lit 317' 2,825' 1" 1" x 25' EL Sucker rods w/ "No" XL guides per rod 3,142' 3,550' 7/8" 7/8" x 25' EL Sucker rods w/ "No" XL guides per rod 6,692' 675' 3/4" 3/4" x 25' EL Sucker rods w/ "No" XL guides per rod 6 ' H 7,367' 400' 3/4" 3/4" x 25' EL Sucker rods w/ 12 XL guides per rod H1 - H3/ 4 7,767' 850' 3/4" 3/4" x 25' EL Sucker rods w/ 4 XL guides per rod Tag fill at 7 — H2/3 10,613' on H4 /5 8,617' 1,425' 3/4" 3/4" x 25' EL Sucker rods w/ "No" XL guides per rod 2/26/13. - H5 C 10,042' 300' 1 -1/2" 1 -1/2" x 25' K Bars (weight bars) Sand & perf D 10,342' 30' 1" 1" x 30" Stabilizer Bar w/ %" Pins (between K Bars) debris. a '"^ , t . r „ Hs E 10,372' 1' Browning On /Off Tool, J -Latch R hand release (Box X Pin) • t .) '' 7''y .� , ;1';',„:=7, F 10,373' 2.5' 1" 1" x 30" Stabilizer Bar w/3/4" Pins H10 G 10,376' 42' 1 -3/4" 1 -3/4" x 42' Insert Pump, RHBC Pump #3332 w/ PA Ring 80 PA Ring, Sand Seal, 2 -1/2" x 1 -3/4" x 36" x 36 -1/2" x 37" RHBC H 10,418' 13' 1 -1/2" Dip Tube PERFORATION DETAIL ON NEXT PAGE NOTE: The Surface Casing annulus was used to down squeeze the 5 -1/2" liner lap during the 1986 workover of this well. TD = 10,904' TVD = 10,783' PBTD = 10,854' PB TVD = 10,734' Updated by DMA 05 -09 -13 • Soldotna Creek Unit n • Well: SCU 31 -08 SCHEMATIC Completed: 10/19/82 Hilcorp Alaska, LLC PTD: 181 -099 API: 50- 133 - 20344 -00 PERFORATIONS Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt SPF Comments Date G1 10,374' 10,384' 10,267' 10,277' 10' 6 2" PJ HC, 60 deg 4/5/2001 H 1 10,442' 10,448 10,333' 10,339' 6' 6 3 -3/8" HC 60 deg 2/27/13 H1 10,445' 10,451' 10,336' 10,342' 6' 6 2" PJ HC, 60 deg 4/5/2001 H3/4 10,467' 10,515' 10,357' 10,404' 48' 6 2" PJ HC, 60 deg 4/5/2001 H2/3 10,469' 10,514' 10,359' 10,403' 45' 6 3 -3/8" HC 60 deg 2/27/13 H4/5 10,532' 10,580' 10,420' 10,467' 48' 6 3 -3/8" HC 60 deg 2/27/13 H5 10,534' 10,565' 10,422' 10,452' 31' 6 1- 11/16" HC 11/5/1999 10,565' 10,580' 10,452' 10,467' 15' 4 1- 11/16" HC 2/23/1998 H6 10,596' 10,610' 10,482' 10,496' 14' 4 2 -1/8" Enerjet 6/8/1995 H8 10,616' 10,634' 10,502' 10,519' 18' 4 2 -18/" DA Slimkone 5/10/1983 6 3 -3/8" Baker TCG 8/4/1986 H8 10,664' 10,672' 10,549' 10,556' 8' 4 2 -18/" DA Slimkone 5/10/1983 6 3 -3/8" Baker TCG 8/4/1986 H8 10,695' 10,703' 10,579' 10,587' 8' 4 2 -18 /" DA Slimkone 5/10/1983 4 3 -3/8" Baker TCG 8/4/1986 H8 10,706' 10,710' 10,590' 10,593' 4' 4 2 -18/" DA Slimkone 5/10/1983 6 3 -3/8" Baker TCG 8/4/1986 H10 10,726' 10,732' 10,609' 10,615' 6' 4 2 -18 /" DA Slimkone 10/7/1982 6 3 -3/8" Baker TCG 8/4/1986 Updated by DMA 05 -09 -13 • • ,,4 I Tit s THE STATE Alaska 011 and Gas °fALASKA Conservation Commission GOVERNOR SEAN PARNELL 333 West Seventh Avenue O e. Anchorage, Alaska 99501 -3572 ALAS B AR 203 Main: 907.279.1433 SCANNED Fax: 907.276.7542 Chad Helgeson Operations Manager Hilcorp Alaska, LLC ` 0 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Re: Swanson River Field, Hemlock Oil Pool, SCU 31 -08 Sundry Number: 313 -085 Dear Mr. Helgeson: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P. Foerster Chair DATED this day of February, 2013. Encl. III RECEIVED STATE OF ALASKA FEB 19 2 013 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS �� <3 OGC 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug for Redril ❑ Perforate New Pod ❑ Repair MC Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate Pull Tubing ' Time Extension ❑ Operations Shutdowi ❑ Re -enter Susp. Wel ❑ Stimulate ❑ Alter CasinC] Other Install Rod Pump, RTP 0 • 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number. , Hilcorp Alaska, LLC 181 -099 Exploratory ❑ Development 0 • 3. Address: 3800 Centerpoint Drive, Suite 100 Stratigraphic ❑ Service ❑ 6. API Number. • Anchorage, Alaska 99503 50-133-20344-00 7. If perforating: 8. Well Name and Number. What Regulation or Conservation Order govems well spacing in this pool? Co 123A Soldotna Creek Unit (SCU) 31-08 Will planned perforations require a spacing exception? Yes ❑ No 151 • 9. Property Designation (Lease Number): 10. Field /Pool(s): FEDA028997 • Swanson River Field / Hemlock Oil • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 10,904 • 10,783 10,854' 10,734' N/A 10,627' (fill) Casing Length Size MD TVD Burst Collapse Structural Conductor 40' 20" 72' 72' Surface 3,354' 10 -3/4" 3,354' 3,354' 3,130 psi 1,580 psi Intermediate Production 10,452' 7 -5/8" 10,452' 10,343' 6,020 psi 3.400 psi Liner 656' 5 -1/2" 10,902' 10,781' 9,190 psi 8,830 psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: 3 -1/2" Tubing Grade: 9.2# N-80 & 9.3# J55 Tubing MD (ft): 1,013; See Attached Schematic See Attached Schematic 2 -7/8" 6 . 5 # N-80 10,142'; 10,564' Packers and SSSV Type: Packers and SSSV MD (t) and TVD (ft): Baker "DB" Pkr; N/A 10,144' MD - 10,045' TVD; N/A 12. Attachments: Description Summary of Proposal 0 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch [] Exploratory ❑ Stratigraphi41 Development [] Service ❑ 14. Estimated Date for 15. Well Status after proiosed work: 02/20/13 Commencing Operations: Oil El Gas ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: 2 -26 - i3 WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: Goi S4I4 - f z GSTOR El SPLUG 111 17. I hereby certify that the foregoing is true mid correct to the best of my knowledge. Contact Chad Helgeson Phone: 907 -777 -8405 Email chelgesonthilcorp.com Printed Name Chad Helgeson Title Operations Manager Signature (.Z%7, j�- Phone 907- 777 -8405 Date 2/19/2013 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number Plug Integrity ❑ BOP Test Mechanical Integrity Test ❑ Location Clearance ❑ Other: y-. 3(�U or. b ,P ' S „ / / p ' 5 14,4; !`• "--1 / .0 r r� `A-c -4;°' . c l M t7 r7aw a/,� 00 '47.- RE3DMS FEB 2 5 Spacing Exception Required? Yes ❑ No Subsequent Form Required: /Q • y0y APPROVED BY 7 Approved by: P 9,,c COMMISSIONER THE COMMISSION Date: 2 - 2_2. -1j 0 242-15 , ♦�6 N A Sa Submit Form and fp o e is / ) Approved application is valid for 12 months from the date of a / roval...� Attachments in Duplicate /7 ` • • Well Prognosis Well: SCU 31-08 Hilcorp Alaska, LL Date: 2/18/2013 Well Name: SCU 31 -08 API Number: 50- 133 - 20344 -00 Current Status: SI Oil Producer Leg: N/A Estimated Start Date: February, 19 2013 Rig: Williams 405 Reg. Approval Req'd? 403 Date Reg. Approval Rec'vd: Regulatory Contact: Donna Ambruz 777 -8305 Permit to Drill Number: 181 -099 First CaII Engineer: Chad Helgeson (907) 777 -8405 (0) (907) 229 -4824 (M) Second Call Engineer: Luke Saugier (907) 777 -8395 (0) AFE Number: 1222653 Current Bottom Hole Pressure: 1,765 psi @ 10,512' MD (Static survey performed on 8/29/13) Maximum Expected BHP: 1,765 psi @ 10,512' MD Max. Allowable Surface Pressure: —0 psi (Based on actual reservoir conditions and min water cut of 95% (0.435psi /ft) with added Safety Factor of 1,000' TVD of oil cap) Static fluid level @ 5,644' Brief Well Summary Soldotna Creek 31 -8 was drilled in 1982 to target H8 and H10 oil reserves in the lower part of the Hemlock formation. Initial production from the H8 and H10 sands exceeded 1100 BOPD. Rapid production decline was attributed to asphaltene and /or paraffin deposits that increased in the wellbore as the GOR increased. These deposits were successfully treated with regular xylene stimulations. In 1986, a rig workover was conducted to replace the production packer and restore casing integrity by squeezing the liner lap. A new gas lift completion was run in 1989 to address a leaking packer and tubing. The upper part of the Hemlock formation (H1 -4 sands) and the Tyonek G -Zone were perforated through tubing in 2001. The well went off production in 2002 with a suboptimal gas lift design unable to lift fl to surface. Notes Regarding Wellbore Condition • Well is currently 51, Tagged fill @ 10,627ft Brief Procedure: 1. Blow -down any pressure on the well and shoot fluid level (echometer) on casing and tubing. 2. MIRU Williams 405 WO Rig 3. RU Slickline, RIH and pull GL Valve at 10,068' 4. Set PX plug in tubing at 10,109'. Circulate oil and any gas from tubing and casing with PW with hot oil truck. Pressure test plug & packer to 2000 psi. (Jug test), chart for 30 min. 5. Pull PX Plug and prong. 6. Shoot fluid level with the echometer, determine static working fluid level. 7. RU E -line, RIH w/ radial torch cutter, Cut 3 -1/2" tubing approximately 10ft above packer @ 10,134' (depending on pup joint length on top of packer). 8. RD E -line ,mss Na l 1 51 &- 9. Set TWC or test plug in FMC tubing hanger, ND tree, NU BOPE and test to 250psi low /3,000psi high, p . ) "'1� annular to 250psi low /1,500psi high (hold each valve and test for 10 -min). Record accumulator / � pre- charge pressures. a. Notify AOGCC 24hrs in advance to witness, be ready to test when /if inspector arrives b. Notify BLM 48 hrs in advance of BOP test • • Well Prognosis Well: SCU 31-08 Hilcorp Alaska, LL) Date: 2/18/2013 c. Ensure winterization package is completely installed 10. Remove TWC, pull tubing hanger and tubing, LD tubing string. 11. PU used 2 -7/8" 8rd 6.5# workstring. 12. PU burn shoe, wash pipe, drill collars and jars, RIH to top of packer. 13. Mill packer @ 10,144' (aft of milling) or until drops. 14. POH and LD milling tools, PU overshot and RIH and latch 3 -1/2" tubing stub and POOH and lay down packer and tubing. 15. RU E -Line, make a GR run w/ 3.5" dummy gun. 16. Perforate H -1, 2/3, 4/5 as shown on the proposed schematic with 3 -3/8" HC guns (99 ft total). 17. RD E -line 18. PU new 2 -7/8" 8rd EUE L -80 tubing with the following BHA. (bull plug, 60ft of blank 3.5" tubing, slotted flow sub, XO, cup type pump seating nipple (approx. 10,500'), XO, Weatherford tubing anchor (approx. 10,300ft), annular depth indicator sub at approx. 6,500ft and chemical injection sub at approx. 4,000ft. 19. Land tubing hanger with tubing in tension (3- 4,000 #'s). 20. ND BOPE, NU tree and test. 21. NU Rod stripper. 22. PU 12ft dip tube (1.25 ", new 1.75" rod pump, RIH with tapered rod string (3/4 ", 7/8" and 1 "), Inspect rods and guides and replace as necessary (3 rods per guide), land the pump, space out the rods, install polish rod. 23. ND rod stripper. 24. RD Williams #405. 25. Roll up Rotoflex pumping unit, couple, and remove LOTO on motor. 26. Return to production. (Notify BLM after 5 days of Production). 27. Notify AOGCC to conduct a no flow test on the well after it has flowed for 5 days and stable production. Attachments: 1. As -built Schematic 2. Proposed Schematic 3. BOP Schematic 4. Proposed Wellhead • • Soldotna Creek Unit Well: SCU 31 -08 SCHEMATIC Completed: 10/19/82 Hilcorp Alaska, LLC PTD: 181 -099 API: 50- 133 - 20344 -00 RKB: 155' All Measurements are RKB to Top of CASING DETAIL Equipment Size WT Grade Top Btm 20" Surface 72' 10 -3/4" 40.5 K -55 Surface 3,354' 20i 20° 33.7 S95 Surface 7 -5/8" 26.4 N80 _ ® 1 29.7 10,452 5 -1/2" 20 N80 10,246' 10,902' TUBING DETAIL 3 -1/2" 9.2 N80 0 1,013' 3 -1/2" 9.3 155 1,013' 10,142' 10 - 3/4'4 ► 2 -7/8" 6.5 N80 10,158' 10,564' JEWELRY DETAIL No Depth ID Item 1 2,119' Camco 3 -1/2" x 1" KBUG GLM I♦ 2 2 10,068' Meria 3 -1/2" x 1 -1/2" TPDX GLM X l 3 3 10,109' Otis 3 -1/2" "X" Nipple 4 10,144' 3.250" Baker 7 -5/8" x 3 -1/2" "DB" Packer w /10' SBE 4 5 10,543' 2.205" Otis 2 -7/8" "XN" Nipple 6 10,564' Baker 2 -7/8" Shear out Sub G1 7 ,H 1 H3, 4 PERFORATIONS Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt SPF Comments Date G1 10,374' 10,384' 10,267' 10,277' 10' 6 2" PJ HC, 60 deg 4/5/2001 XN 5 H5 H1 10,445' 10,451' 10,336' 10,342' 6' 6 2" P1 HC, 60 deg 4/5/2001 H3, 4 10,467' 10,515' 10,357' 10,404' 48' 6 2" P1 HC, 60 deg 4/5/2001 6 10,534' 10,565' 10,422' 10,452' 31' 6 1- 11/16" HC 11/5/1999 H5 10,565' 10,580' 10,452' 10,467' 15' 4 1- 11/16" HC 2/23/1998 H6 H6 10,596' 10,610' 10,482' 10,496' 14' 4 2 -1/8" Enerjet 6/8/1995 H8 10,616' 10,634' 10,502' 10,519' 18' 4 2 -18 /" DA Slimkone 5/10/1983 - 6 3 -3/8" Baker TCG 8/4/1986 H8 10,664' 10,672' 10,549' 10,556' 8' 4 2 -18/" DA Slimkone 5/10/1983 6 3 -3/8" Baker TCG 8/4/1986 H10 H8 10,695' 10,703' 10,579' 10,587' 8' 4 2 -18/" DA Slimkone 5/10/1983 4 3 -3/8" Baker TCG 8/4/1986 H8 10,706' 10,710' 10,590' 10,593' 4' 4 2 -18/" DA Slimkone 5/10/1983 6 3 -3/8" Baker TCG 8/4/1986 H10 10,726' 10,732' 10,609' 10,615' 6' 4 2 -18/" DA Slimkone 10/7/1982 6 3 -3/8" Baker TCG 8/4/1986 NOTE: The Surface Casing annulus was used to down squeeze the liner lap during the 1986 workover of this well. 5 -1/2" TD = 10,904' TVD = 10,783' PBTD = 10,854' PB TVD = 10,734' Updated by DMA 02 -19 -13 • II • Soldotna Creek Unit PROPOSED Well: SCU 31 -08 Completed: 10/19/82 SCHEMATIC PTD: 181 -099 Hilcorp Alaska, LLC API: 50- 133 - 20344 -00 RKB: 155' CASING DETAIL All Measurements are RKB to Top of Size WT Grade Top Btm Equipment 20" Surface 72' A 1 10 -3/4" 40.5 K -55 Surface 3,354' 1 33.7 S95 Surface 7 -5/8" 26.4 N80 20 B 29.7 10,452' 11 5 -1/2" 20 N80 10,246' 10,902' 1. TUBING DETAIL 2-7/8" 6.4 L80 EUE 0 ±10,300' 3/8" 5.5. 0 ±4,000' 71 2 10 -3/4'4 T ■ c 0 JEWELRY DETAIL 3 # Depth' Length' ID" OD" Description I 1 15.5 1.7 2.441 Tubing Hanger 2 ±4,000 2.32 2.43 4 Chemical Injection Mandrel ° 3 ±6,500 1 2.441 4.5 Marker joint 1 4 ±10,300 2.32 2.441 4.5 Tubing Anchor I 5 ±10,500 0.65 2.441 3.5 Seating Nipple E u lI 6 ±10,502 0.5 2.992 3.5 Crossover 7 ±10,505 10 2.992 3.5 Slotted Sub 4 8 ±10,515 61 2.992 3.5 Tubing 9.3# - 3 -1/2" (mud Anchor) G1 9 ±10,575 0.44 2.992 3.8 Plug 7 -5/8 ", 5 H1 H3, 4 ROD DETAIL 6 F A ±2.25 40 - 1.5 Polish rod 7 G B ±40 2,220 - 1 1" EL rods with 3 per XL guides, T Coupling 8 _. H5 C ±2,260 3,550 - 7/8 7/8" EL rods with 3 per XL guides H D ±5,800 4,330 - 3/4 %" EL rods w /3,5,or12 per XL guides 9 E ±10,130 325 - 1.5 Sinker Bars (13 x 25') - H6 RHBC rod pump w -3/4" SR pin x 1.8024 -14 Tag fill at F ±10,460 40.92 - 2.25 ( box 2.5 "x1.75 "x 36'x36.5'x37) ' 10,627' on G,; +` 8/29/12 �` �s�a - 8 G ±10,500 - - 2.313 Seating cup H ±10,512 12' 1.26 1.66 Dip tube perforated on bottom = H10 PERFORATION DETAIL ON NEXT PAGE 5 -1/2" NOTE: The Surface Casing annulus was used to down squeeze the liner lap during the 1986 workover of this well. TD = 10,904' TVD = 10,783' PBTD = 10,854' PB TVD = 10,734' Updated by DMA 02 -19 -13 • Soldotna Creek Unit PROPOSED Well: SCU 31 -08 Completed: 10/19/82 Hilcorp Alaska, LLC SCHEMATIC PTD: 181 -099 API: 50- 133 - 20344 -00 PERFORATIONS Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt SPF Comments Date G1 10,374' 10,384' 10,267' 10,277' 10' 6 2" P1 HC, 60 deg 4/5/2001 H1 10,445' 10,451' 10,336' 10,342' 6' 6 2" P1 HC, 60 deg 4/5/2001 H1 10,442 10,448 6' 6 3 -3/8" HC 60 deg Feb 2013 / I H3, 4 10,467' 10,515' 10,357' 10,404' 48' _ 6 2" PJ HC, 60 deg 4/5/2001 H2/3 10,469' 10,514' 45' 6 3 -3/8" HC 60 deg Feb 2013 ' H4/5 10,532' 10,580' 48' 6 3 -3/8" HC 60 deg Feb 2013 / H5 10,534' 10,565' 10,422' 10,452' 31' 6 1- 11/16" HC 11/5/1999 10,565' 10,580' 10,452' 10,467' 15' 4 1- 11/16" HC 2/23/1998 H6 10,596' 10,610' 10,482' 10,496' 14' 4 2 -1/8" Enerjet 6/8/1995 H8 10,616' 10,634' 10,502' 10,519' 18' 4 2 -18/" DA Slimkone 5/10/1983 6 3 -3/8" Baker TCG 8/4/1986 H8 10,664' 10,672' 10,549' 10,556' 8' 4 2 -18/" DA Slimkone 5/10/1983 6 3 -3/8" Baker TCG 8/4/1986 H8 10,695' 10,703' 10,579' 10,587' 8' 4 2 -18/" DA Slimkone 5/10/1983 4 3 -3/8" Baker TCG 8/4/1986 H8 10,706' 10,710' 10,590' 10,593' 4' 4 2 -18/" DA Slimkone 5/10/1983 6 3 -3/8" Baker TCG 8/4/1986 H10 10,726' 10,732' 10,609' 10,615' 6' 4 2 -18/" DA Slimkone 10/7/1982 6 3 -3/8" Baker TCG 8/4/1986 Updated by DMA 02 -19 -13 - • • II Swanson River SCU 31 -08 02/15/2013 Ibkr.rp 11a.La. LLC Swanson River Williams BOP 2013 Rh i ilia III P 3.46' Ill 1 . 1 11 I fl Shaffer LWS -- . * • 2.75' 11" 5M _ 2 1/16 10M Choke and Kill � 1∎.. . . Valves III ill lit Ili lit . 5 t t 200• , • % '.. 0 , ial Iti III 1l1 Iii !1 will III I!i Om 2.00 LIT ti, D I d Mil 40� 1® o 11111 11111 1 1 1 1111 !II in (I j » J I .I.., 1 O P f • II • Swanson River SCU 31 -0 02/16/2013 Hilrnrp liLiekn.l,l.(. Swanson River Tubing hanger, Seaboard, SCU 31 -08 ECO tension, 7 1/16 5M X 2 103 "X75/8 "X27/8 7 /8EUE lift and susp,w /2'/: type H BPV, 3/8 control line, 5" slickneck, left to release, right to engage Full stainless steel for chemical injection Special Cross, 2 9/16 5M FE X 2 7/8 EUE 8rd w/ 2- 2 1/16 5M SSO Valve, wing, WKM -M, 2 1/16 �� Valve, wing, WKM -M, 2 1/16 SM FE, HWO, DD trim - 5M FE, HWO, DD trim illi ''' 0 ''' - .el 1 1 .:. -NM Adapter, Seaboard, 7 1/16 J ' __ 5MFEX29 /165Mw /5 "PP Grade Level seal pocket, Y: control line _s l exit, alloy material Tubing head, FMC -TC, 11 5M = ' X 71/16 5M, w/ 2- 2 1/16 5M SSO, BG bottom prep +.1111 If I II - i f i li . 1 41L . 11 ' A. 4,, k,,,Il ;., _ _ . , . . . ,i, ii, Alpi. 7 Casing head, Gray, 11 5M X 10 %SOW,w /2 -2" LPO ∎ 1 #I �., _ ICI VIII it / 1 Page l of l • Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Wednesday, February 20, 2013 9:28 AM To: 'Chad Helgeson' Cc: Wade Hudgens - (C); Regg, James B (DOA) Subject: RE: SCU 31 -8 Approval (PTD 181 -099) Chad, You have verbal approval to proceed with the RWO (including prep work) on SCU 31 -08 (PTD 181- 099) as proposed in your sundry application. The Commissioners are requesting that you make every effort to give us the proper lead time on these sundry requests or in the future they may not be approved verbally. Regards, Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Chad Helgeson [mailto:chelgeson @hilcorp.com] Sent: Wednesday, February 20, 2013 7:26 AM To: Schwartz, Guy L (DOA) Cc: Wade Hudgens - (C) Subject: SCU 31 -8 Approval Guy, We are ready and rigged up to start working on the SCU 31 -8. We actually started on the slickline work yesterday. Can we get verbal approval to complete the a -line work and then nipple down the tree and NU the BOP stack and test today. We will plan to pressure test the casing after we circulate the hole full and cleaned out. We gave Jim notice yesterday that we wanted to test this afternoon, hoping we would have approval for the work. Thanks for the help. Chad Helgeson Operations Manager North Kenai Asset Team Hilcorp Alaska, LLC Office: 907 - 777 -8405 Mobile: 907 - 229 -4824 2/21/2013 / Unocal Corporation ~ P.O. Box 196247 Anchorage, AK 99501 Telephone (907) 263-7660 UNOCAL ) Dan Williamson Drilling Manager Friday, March 24, 2000 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Attn: Mr. Robert Christensen Subject: Soldotna Creek Unit Well SCU 31-8 APl No. 50-133-20344-00 10-404 Perforate H4 bench Dear Mr. Christensen: ~.~ ~ _ © ot ~ Please find enclosed in duplicate Form 10-404 for the reperforation of the H4 bench in well SCU 31-8, The following interval was perforated on 11/5/99: O IGiNAL Bench Top Bottom Feet H4 10,534 10,565 31 Total' 31 RECEIVED if you have any questions, please contact Ralph Holman at 263-7838. 10 .0t)0 Dan Williamson Drilling Manager STATE OF ALASKA ( ALASKA el AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown: Stimulate: Plugging: Perforate: X Pull tubing: Alter casing: Repair well: Other: 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Union Oil of California (Unocal) Development: X 155' KB feet ,,, 3. Address Exploratory: 7. Unit or Property name Strafigraphic: Soldotna Creek Unit P.O. Box 196247 Anchorage, Alaska 99519-6247 Service: 4. Location of well at surface 8. Well number 1902' S & 1968' W of NE Cor., Sec. 8, T7N, R9W, SM SCU 31-8 At top of productive interval 9. Permit number/approval number 1254' S & 1367' W of NE Cor., Sec. 8, T7N, R9W, SM 81-0099 At effective depth 10. APl number 1218' S & 1313' W of NE Cor., Sec. 8, T7N, R9W, SM 50-133-20344-00 At total depth 11. Field/Pool 1213' S & 1308' W of NE Cor., Sec. 8, T7N, R9W, SM Swanson River/Hemlock · 12. Present well condition summary Total depth: measured 10,904 feet Plugs (measured) true vertical 10,873 feet Effective depth: measured 10,854 feet Junk (measured) true vertical 10,734 feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 40' 20" 72' 72' Surface 3353' 10-3/4" 1490 sx 3383' 3383' Intermediate 10,424' 7-5/8" 872 sx 10,452' 10,341' Production Liner 656' 5-1/2" 86 sx 10,902' 10,781' Perforation depth: measured 10534-10565, 10616-10634, 10664-10672, 10695-10703, 10706-10710, 10726-10732 true vertical 10422-10452, 10501-10519, 10548-10556, 10578-10586, 10589-10593, 10609-10615 Tubing (size, grade, and measured depth) 3-1/2", N-80 & J-55 at 10142'; 2-7/8", N-80 from 10158'-10564' Packers and SSSV (type and measured depth) Baker "DB" pkr. at 10144' .o_ :P.i::IV 13. Stimulation or cement squeeze summary a ,~,,,,, ---- w - Intervals treated (measured)ORIGINAL ,,. Treatment description including volumes used and final pressure j~0r~ &~ C005, Co~~!~ 14. Representative Daily Average Production or Injection Data ........ - OiI-BBL Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 25 4360 20 900 700 Subsequent to operation 26 5800 14 1200 900 1 5. Attachments: 16. Status of well classification as: Copies of Logs and Surveys run: Daily Report of Well Operations: Oil: %/(, Gas: ' Suspended: Service: 17. I hereby certify that the foregoing is true and correct to the b~st~f my knowledge: Signed:~~/~ ~~~~ Title: ~F~"/~//~(~' ~ ,, Date: Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE Unocal Corporation O(~D Oil & Gas Operations 909 West 9th Avenue, R ox 196247 Anchorage, Alaska 99519-6247 Telephone (907) 276-7600 UNOCAL December 19, 1995 Alaska Ms. Joan Miller Statistical Technician Alaska Oil & Gas Conservation Comm. 3001 Porcupine Drive Anchorage, Ak. 99501-3192 Dear Ms. Miller: ORIGINAL Re: Soldotna Creek Unit- Well SCU 31-8 APl Number 50-133-20334-00 This is to inform you that on 6/8/95 Unocal reperforated the following interval in SCU 31-8 in the Soldotna Creek Unit: BENCH TOP (MD) BOTTOM (MD) FEET HB 1 10596' 10610' 14' TOTAL 14' RECEiVEu DEC 2 9 1995 Alaska 0il & Gas Cons. Commission Anchorage Verytrulyyours, /, ~ . Candace Williams 1. Operations performed: Operation shutdown Stimulate Plul~ Perfora~'/~J .... Pull tubiw -- ? i(~ Pull tubin9 After casin9 Repair well 2. Name of Operator 5. Type of Well: 6. Datum elevation Development x'~*~ / UNION OIL COMPANY OF CALIFORNIA (UNOCAL) Exploratory KB 155', GL 129' 3. Address Stratigraphic 7. Unit or Property name P.O. BOX 196247 ANCHORAGE, AK 99519 - 6247 Service 8oldotna Creek Unit 4. Location of well at surface 8. Well number 1~)2' FNL, 1~:~8' FEL, Sec. 8, 'I-/N, RgVV, SM SCU 31-8 At top of productive interval 9. Permit number 1269' FNL, 1~:~8' FEL, Sec. 8, T-/N, RgVV, SM 81-0099 At effective depth 10. APl number 1218' FNL, 1313' FEL, Sec. 8, 'I-/N, RGW, SM 50-133-20344-00 At total depth 11. Field/Pool 1213' FNL, 1308' FEL, Sec. 8~ TTN~ RgW~ SM Swanson River/Hemlock 12. Present well condition summary Total depth: measured 10,G04 feet Plugs (measured) true vertical 10,738 feet Effective depth: measured 10,860 feat Junk (measured) true vertical 10,740 feet Casing Len~d~ Size Cemented Measured depth True vertical depth Structural Conductor 72 20" Driven 72' 72' Surface 3354' 10-3/4" Yes 3354' 3354' Intermediate Production 10,424' 7-5/6" Yes 10,452' 10,341' Liner 656' 5-1/2" Yes 10246' - 10902' 10143' - 10782' Perforation depth: measured 10593-10610'; 10616-10634'; 10664-10672'; 10695-10703'; 10706-10710'; 10726-10721' true vertical 10478-10495'; 10501-10519'; 10548-10556'; 10578-10586'; 1 0589-10593' 10608-10614' 2-7/8", 6.5#, N-80 from 10158'-10564'i %l..V L_ iVI,.. Packers and SSSV (type and measured depth) Baker 7-5/8" DB @ 10144' 13. Stimulation or cement squeeze summary ~-~ 2 cj Intervals treated (measured) ~8~k8 0ii & Gas Cons. C0mmi: Treatment description includin9 volumes used and final pressure ,~dlch0rs~8 14. Representative Daily Average Production or Injection Data Oii-Bbl Gas-Mcf Water-Bbl Casing Data Tubing Pressure Prior to well operation 6/5/95 54 3342 0 500 500 Subsequent to operation 6/9/95 58 ~ 3880 4 700 1500 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run Daily Report of Well Operations~ ~, Oil X Gas Suspended Service 17.1 hereby certify that the for~,fgo, in~is tru~ ~nd c~)~~est of my knowledge. ' ' Signed G. Russell Schmidt/r~~'~ J/ ~{J [[~~ ~C~'~e Drilling Manager Date ~?-.l~{i Form 10-404 Rev 06/15/88 v u ~ SUBMIT IN DUPLICAT-' ~ion Unocal Corporation P.O. Box 196247 Anchorage, AK 99519 (907) 263-7805 UNOCAL4 Marie Vaughn Drilling Engineer PED Tuesday, July 18, 1995 Mr. Russ Douglas AOGCC 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Douglas: Between May 28, 1995 and June 8, 1995 fill was cleaned out of Swanson River Field well SCU 31-8 (APl #50-133-20344) from 10,605'-10,622' WLM and the following intervals were perforated: Hemlock bench 6 from 10,596'-10,610' with 2-1/8" Enerjet guns, 4 SPF, 0 deg phasing. Production test before (5/07/95) 45 BOPD, 6 BWPD, 3.3 MMCFD. Production test after (6/09/95) 58 BOPD, 4 BWPD, 3.9 MMCFD. Sincerely, Marie L. Vaughn MLV/leg RECEIVED JUL 2 7 t995 Alaska 0il & Gas Cons. Commission Ancho,': [ .... STATE OF ALASKA , ALA! . OIL AND GAS CONSERVATION COMI~ :)N REPORT OF SUNDRY WELL OPERATIO/I . 1. Operations performed: Operation shutdown __ Stimulate __ Plugging _ _ Perforate X_._ Pull tubing Alter casing Repair well Pull tubing OtherX' .~~ ~g Cleanout 2. Name of Operator - - -- 15. Type of V~e~l: -- 6. Datum e~-e~/ation t x , "/,// Union Oil Company of California (Unocal) I Exploratory - 155 KB ' ~',, feet 3. Address I Stratigraphic-- ~ Property name P.O. Box 196247 Anchorage, AK 99519 I Service _-~ Soldotna Creek Unit 4. Location of well at surface 1902' FNL, 1968' FEL, Sec. 8, 'iTN, RDW, SM At top of productive interval 1269' FNL, 1968' FEL, Sec. 8, '[TN, RDW, SM At effective depth 1218' FNL, 1313' FEL, Sec. 8, 'lTN, RDW, SM At total depth 1213' FNL, 1308' FEL, Sec. 8, T7N, RDW, SM 8. Well number SCU 31-8 9. Permit number/approval number 10. APl number 50-133-20344 11. Field/Pool Swanson River Field 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural Conductor 40' Surface 3354' Intermediate 10,424' Production 656' Liner Perforation depth: 10,904' feet Plugs (measured) 10,904'- 10,860' 10,783' feet 10,860' feet Junk (measured) 10,740' TVD feet Size Cemented Measured depth True vertical depth 20" 72' MD 72' TVD 10-3/4" 3354' MD 3354' TVD 7-5/8" 10,452' MD 10341' TVD 5-1/2" 10,902' MD 10781' TVD measured 10616'-10634'; 10664'-10672'; 10695'-10703'; 10706'-10710'; 10726'-10732' MD true vertical 10501'-10519'; 10548'-10556'; 10578'-10586'; 10589'-10593'; 10608'-10614' TVD Tubing (size, grade, and measured depth) 3-1/2", 9.3#, J-55 to 10142', 2-7/8", 6.5#, N-80, 10142'-10564' Packers and SSSV (type and measured depth) Baker 7-5/8 DB @ 10144' MD 13. Stimulation or cement squeeze summary Cleaned out fill f/10,605'- 10,622' WLM. Intervals treated (measured) Perforated Hemlock bench 6 -F/10,596'-10,610' with 2-1/8" Enerjet, 4 SPF, 0 deg phasing Treatment description including volumes used and final pressure None 14. Prior to well operation Subsequent to operation Representative Daily Average ProductiOn or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 45 3300 6 58 3900 4 Tubing Pressure 15. Attachments J 16. Status of well classification as: Copies of Logs and Surveys run I Daily Report of Well Ope~a. tio/~s ~ ~, ~ I Oil x_ Gas __ Suspended__ Service 17.1 hereby certify that the fo~:j~n,g,~':;~ll~'~~ct to the best of my knowledge. R E C ~ iV E D Signed G. Russell Schmidt,jl~.~ Title Drilling Manager Date Form 10-404 Rev 06/15/88 07/19/95 JUL 2 7 199 UBMIT IN DUPLICATE 0il & Gas Cons. Commission Anch0,? .~? SCU 31-8 DAY 1-2 (05/28-29/95) COMMENCE OPS AT 12:00 HRS ON 5/28/95. MOVE FROM SCU 32-8 TO SCU 31-8. R/U DOWELL CTU AND TEST BOPE. M/U MOTOR AND 2.2" CARBIDE MILL. ATTEMPT TO RIH COULD NOT PASS SWAB VALVE. SWAB VALVE WOULD NOT FULLY OPEN. CHANGE OUT SWAB VALVE. R/U BOP'S SHUT DOWN FOR NIGHT. DAY 3 (05/30/95) RU INJ. & LUB. RIH W/2.125" BHA & 2.15" MILL. RIH & TAG @ 10,582'. MILL FILL TO 10,588'. PUMP XANVIS SWEEP. INCREASED WOB TO 9000# MILLTO 10,590'. PUMP 30 BBL XYLENE SOAK. RIH STALL MOTOR @ 10,585'. PUMP ANOTHER XYLENE SOAK. ALLOW TO SOAK 1.5 HRS. RIH KEEP STALLING MOTOR. PUMP XANVIS SWEEP POOH. RETURNS: XYLENE W/NO SOLIDS ASPHALTENES, PLASTIC YELLOW STRANDS (1"-3" LONG). SHUT DOWN FOR THE NIGHT. DAY 4 (05/31/95) R/D LUBRICATOR. MILL HAD YELLOW NYLON ROPE JAMMED IN IT. MOTOR HAD SPIRAL SCARS (POSSIBLE SLICKLINE WRAPPED AROUND MOTOR) NO RECORD OF EITHER IN FILES. RJU SLICKLINE. RAN 1.8 lB TAGGED @ 10632' WLM FOUND A COUPLE OF MARKS NO GOOD INDICATION. RIH W/2 PRONG GRAB. MADE 3 RUNS NO RECOVERY INNER TEETH BENT INWARD PRONG BENT IN. FOUND MORE NYLON ROPE IN JARS. RIH W/BAILER RECOVERED METAL SHAVING, GRAVEL AND SAND. RIH W/lB NO GOOD INDICATION. RIH W/1.8 OVER SHOT COULD NOT LATCH. (NOTE APPEARS TO BE UNIDENTIFIED JUNK IN HOLE COULD MAKE NO PROGRESS W/SLICKLINE OR CTU, WILL RIG DOWN CTU AND MOVE TODAY 6/1/95). DAY 5 (06/01/95) 8.4 PPG OPERATIONS SUSPENDED 12:00 HR ON 6/1/95 AWAITING ADDITIONAL SLICKLINE WORK. R/D CTU MOVE TO SCU 41-8 LOCATION. RECEIVED L ?-- 7 1995 Gas Cons. Commission Ancho,?? ALASKA OIL AND GAS CONSERVATION COMMISSION WALTER J. HIGKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7~2 June15,1994 Russell Schmidt Union Oil Company of California P O Box 190247 Anchorage, Alaska 99519 RE: 8't~'?~ SOLDOTNAC:R~~IT 31-08 83-0053 TRADING BAY UNIT D-42 85-0311 TRADING BAY UNIT D-43RD Dear Mr. Schmidt, A review of our well records and correspondence indicates the referenced wells are missing directional Surveys. This requirement was indicated on the permit to drill. The survey Should be submitted with the form 10-407 Well Completion Report. This is a compliance check I conducted for missing required data as stated in 20 AAC 25.050 (f). This data has not previously been requested. If you have the surveys, please make a copy and mail to me to correct this problem and update our well files. Sincerely, Steve McMains Statistical Technician JUNE 17, 1994 09:46 UNOCAL/ALASKA . EPARJJD . API# 501332034400 OPERATOR CHEVRON Survey datum Survey elevation Survey company Survey method Survey date . 155.00 GREATLAND SINGLE-SHOT 08/23/82 Surface location projection township 340269.0 2454118.00 STATE ALK4 S08 T07N R09W SM Measured Vertical Depth Depth 0.00 0.00 493.00 493.00 982.00 981.99 1477.00 1476.97 1973.00 1972.95 2499.00 2498.93 2995.00 2994.91 3404.00 3403.89 3924.00 3923.76 4363.00 4362.38 4467.00 4466.22 4529.00 4528.11 4601.00 4599.99 4740.00 4738.75 4834.00 4832.57 4988.00 4986.28 5174.00 5171.95 5391.00 5388.52 5640.00 5636.87 6133.00 6128.34 6289.00 6283.78 6504.00 6497.96 6779.00 6771.74 7021.00 7012.63 7251.00 7241.91 7460.00 7450.36 7497.00 7487.24 7529.00 7519.13 7572.00 7561.89 7639.00 7628.25 Calculation method Reference Subsea Drift Depth Angle Azimuth Coordinates X Y 155.00 0.00 0.00 -338.00 0.25 351.00 -826.99 0.50 339.00 -1321.97 0.50 64.00 -1817.95 0.50 184.00 340269 2454118 340269 2454119 340268 2454122 340270 2454125 340272 2454123 -2343.93 0.50 77.00 -2839.91 0.50 146.00 -3248.89 0.50 21.00 -3768.76 2.00 6.00 -4207.38 2.75 312.00 340275 2454121 340279 2454119 340282 2454119 340285 2454130 340279 2454147 -4311.22 3.50 325.00 -4373.11 3.25 328.00 -4444.99 3.25 328.00 -4583.75 3.50 326.50 -4677.57 3.50 326.50 340275 2454151 340273 2454154 340271 2454158 340267 2454165 340264 2454169 -4831.28 3.50 327.50 340259 2454177 -5016.95 3.25 328.50 340253 2454187 -5233.52 4.00 329.50 340246 2454199 -5481.87 4.25 327.50 340237 2454214 -5973.34 4.75 344.50 340222 2454249 -6128.78 5.00 347.50 340219 2454262 -6342.96 5.00 352.50 340216 2454281 -6616.74 5.75 354.00 340213 2454306 -6857.63 5.25 355.00 340211 2454330 -7086.91 3.75 1.50 340211 2454348 -7295.36 4.50 11.50 340213 2454362 -7332.24 4.50 19.50 340214 2454365 -7364.13 5.00 31.00 340215 2454368 -7406.89 7.00 44.50 340217 2454371 -7473.25 8.75 49.50 340224 2454377 : Radius of curvature (default from database) : Map projection STATE ALK4 Measured Vert - Subsea Drift ,~ Coordinates Depth Depth Depth Angle Azimuth X Y 7730.00 7718.04 -7563.04 10.00 49.50 340236 2454387 7792.00 7779.04 -7624.04 10.50 50.50 340244 2454394 7885.00 7870.37 -7715.37 11.25 48.50 340258 2454405 7998.00 7980.90 -7825.90 12.75 48.50 340276 2454420 8071.00 8051.76 -7896.76 15.00 47.50 340289 2454432 8204.00 8180.00 -8025.00 15.75 45.50 340315 2454456 8324.00 8295.49 -8140.49 15.75 45.00 340338 2454478 8393.00 8362.02 -8207.02 15.00 54.50 340352 2454490 8422.00 8390.01 -8235.01 15.25 59.50 340359 2454494 8575.00 8537.71 -8382.71 15.00 62.50 340394 2454513 8764.00 8719.94 -8564.94 15.75 61.50 340438 2454536 9132.00 9073.45 -8918.45 16.50 62.50 340529 2454583 9358.00 9290.01 -9135.01 16.75 63.50 340587 2454611 9649.00 9568.47 -9413.47 17.00 62.50 340663 2454648 9861.00 9771.74 -9616.74 16.00 62.50 340717 2454675 10085.00 9987.59 -9832.59 15.00 63.50 340770 2454702 10270.00 10166.49 -10011.49 14.50 63.50 340813 2454722 10487.00 10376.45 -10221.45 14.75 61.50 340862 2454747 10617.00 10502.45 -10347.45 13.75 57.00 340890 2454763 10771.00 10652.79 -10497.79 11.25 52.50 340917 2454782 10869.00 10748.86 -10593.86 11.50 52.50 340932 2454793 10904.00 10783.16 -10628.16 11.50 52.50 340938 2454798 Calculation method : Radius of curvature (default from database) Reference : Map projection STATE ALK4 ARCO ALASKA INC. Cook Inlet/New Ventures Engineering TRANSM1TrAL 8427 TO:. Commissioner DA]E: 8/28/1990 _ FROM: Scott Jepsen COMPANY: ARCO Alaska, Inc 'WELL NAME: Listed below Transmitted herewith are the following Blue Sepia Sepia Line Folded Rolled Mylar Tape 'SCU 3i:8 COMPLETION RECORD 1 1 _ Receipt Acknowledgement:~ Return reciept to ARCO ALASKA, Inc. ATrN: Judy Bocglcr ATO 1390A Post Office Box 100360 Anchorage, AK 99510-0360' AUG ~ 0 ~990 Alaska 0il & aaa Cons. ~0 'Anchorage ARCO Alaska, Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Cook Inlet Engineering June 18, 1990 Mr. C. V. Chatterton, Chairman Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 RE: Well SCU 31-8 Dear Mr. Chatterton: Attached is a Report of Sundry Well Operations for perforating the H6 interval in Well SCU 31-8. We perforated 13' of the H6 sand, from 10,593' to 10,606' MD, with a 1-11/16" strip gun @ 4 spf. If you have any questions please contact David Pursell at 263-4258. Sincerely, T. Wellman Regional Engineer TW:DAP:ch:0033 Attachment cc: S.W. Ohnimus A. I~ Kukla UNOCAL Corporation Marathon Oil Company RECEIVED JUN 2 0 1990 Alaska Oil & Gas Cons. Commission ~mchorage ARCO Alamka, ;nc. I, a Sub~m~ry of Atlantic Richfield Company STATE OF ALASKA A~ _,KA OIL AND GAS CONSERVATION COMI[ .~ION REPOFIT OF SUNDRY WELL OPEFIATION 1 G 1 N !. 1. Operations performed: Operation shutdown __ Stimulate __ Plugging __ Perforate X Pull tubing ~ Alter casing __ Repair well __ Pull tubing ~ Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 1902' FNL, 1968' FEL, Sec. 8, T7N, Rgw, SM At top of productive interval 1269' FNL, 1968' FEL, Sec. 8, T7N, Rgw, SM At effective depth 1218' FNL, 1313' FEL, Sec. 8, T7N, Rgw, SM At total depth 1213' FNL, 1308' FEL, Sec. 8, T7N, R9W, SM. 6. Datum elevation (DF or KB) 155' KB 7. Unit or Property name Soldotna Creek Unit 8. Well number SCU 31-8 9. Permit number/approval number i10. APl number ,50-- 133-20344 11. Field/Pool Swanson River Field feet 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 10,904' MD feet 10,783' MD~et 10,860' MDfe~ 10,740'TVDfeet Plugs (measured) Junk (measured) 10,904 - 10,860' Casing Length Size ~t~Y~ Conductor 40 ' 20" Surface 3,354 ' 10-3/4" Intermediate 10,424 ' 7-5/8" Production 656 ' 5-1/2" Perforation depth: measured Cemented' Measured depth 10,616-10,634'; 10,664-10,672'; true vertical 10,501-10,519'; 10,548-10,556'; Tubing (size, grade, and measured depth) 3-1/2", 9.3#, J-55 to 10,142', 2-7/8", 6.5# N-80, Packers and SSSV (type and measured depth) Baker 7-5/8" DB@ 10,144' MD 72' MD 3,354' MD 10,452' MD 10,902' MD 10,695-10,703'; 10,578-10,586'; 10,706-1.0,710'; 10,589-10,593'; 10,142-10.564' 13. Stimulation or cement squeeze summary Intervals treated (measured) True vertical depth 72' TVD 3,354' TVD 10,341' TVD 10,781' TVD 10,726-10,732' MD. 10,60~ ~ ~'l 91~/- D JUN 2 0 1990 Alaska 0il Anchorage Perforated 10,593' - 10,606' MD with 1-11/16" strip gun ~ 4 spf. Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 183 8700 6 75 1260 Subsequent to operation 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 249 11700 9 1180 16. Status of well classification as: Oil _~ Gas ~ Suspended Service 1375 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Cook Inlet Regional Engineer Title Date /' Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE ,ARCO Alas,,ka,,, In/~~ <~ 8ub&ld~r~ ot Atl~ntio fl ohfi~ cl WELL CONTRACTOR RIEMARK8 ...._ JPBDT FIELD. DISTRICT. STA'r~ WELL SERVIUb l°^Y~I~A,~ ' ~_.~c~. -/~--~. .... 90o 70 ........ /,~ !'1: ~o '~.co Alaska Inc.- Swanson Ri~~ 'Wel_l- scu 31-8 (~- APl#: 133-20344-00 Spud Date: 6/82 Completion Date': 10/82 Original RKB: 155' Hanger Type: Gray Top of Hemlock: 10,440 Max. Hole Angle: 17° ield Well Type: Producer Last Workover: 4/14/89 Hanger: CWC-F6 Angle @ Hemlock: 14° All Depths are RKB MD to Top of Equipment. k.1 NOTE: PBTD = TD = Jewelry 1 2119 2 10,068 3 10,109 4 10,144 5 10,531 6 10,564 Minimum ID: Camco 3-1/2' x I*KBUG GLM Merla 3-1/2' x 1-1/2' TPDX GLM Otis 3-1/2" 'X' Nipple Baker 7-5/8" x 3-1/2" 'DB' Packer I.D. 3.250 w/10' SBE Otis 2-7/8" 'XN' Nipple I.D. 2.205 Baker 2-7/8 Shear out Sub 2.205" ~ 10.531 (Offs 2-7/8" 'XN' nipple} Casing and Tubing ~ Weight ~ 20" 0 72' 10-3/4" 40.5#/ft K-55 0 3354' 7-5/8" 33.7 #/It S95 0 10,452' 26.4 #/It Nd0 29.7 #/ft 5-1/2" 20 #/ft Nd0 10,246 10,902 3-1/2' 9.2# Nd0 0 1013' 3-1/2' 9.3# J-55 1013' 10142' 2-7/8' 6.5# Nd0 10,158' 10,564' Description Conductor Pipe Surface Casing Production Casing Liner Tubing Tubing Tubing Perforation Data ~ Zone FT SPF ~ Comments 10,616 - 10,634 H8 18 4 5/10/83 2-1/8" DA Slimkone 6 8/4~86 3-3/8" Baker TCG 10,664 - 10,672 H8 8 4 5/10/83 2-1/8" DA Slimkone 6 8/4/86 3-3/8' Baker TCG 10,695 - 10,703 H8 8 4 5/10/83 2-1/8" DA Slimkone 6 8/4/86 3-3/8" Baker TCG 10,706 - 10,710 H8 4 4 5/10/83 2-1/8" DA Slimkone 6 8/4/86 3-3/8" Baker TCG 10,726 - 10,732 H10 6 4 10/7/82 2-1/8" DA Slimkone 6 8/4/86 3-3/8" Baker TCG The Surface Casing annulus was used to downsqueze the liner lap during the 1986 workover of this well. 10,854' E¢E IV E D w,,, scu By: JWR - 4/27/88 JUN 2 0 1990 Revised 'JLa 5/8/89 A~as~(a 0JJ & Gas Corls. Commission Anchorage ARCO Alaska, Inc{f Post Office'~,~× '= ~0360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Cook Inlet/New Ventures Engineering May 7, 1990 Mr. C. V. Chatterton, Chairman Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 RE: Well SCU 31-8 Dear Mr. Chatterton: Attached is an Application for Sundry Approval to perforate the H6 interval in Well SCU 31-8. We propose to perforate 14' of the H6 sand, from 10,593' to 10,606' MD, with a 1-11/16" strip gun @ 4 spf. If you have any questions please contact David Pursell at 263-4258. Sincerely, T. Wellman Interim Manager TW:DAP:ch:0031 Attachment RECEIVED 0 9 ]990 ^laska 0ii & Gas Cons. C0mmlsslorl Anchorag~ cc: S.W. Ohnirnus A. R. Kukla UNOCAL CorporaUon Marathon Oil Company ARCO Alaska, inc. is a Subsidiary of AtianticRichfieidCompany ALASKA OILAND GAS CONSERVATION COMMISSION 0 ~t ~ 6 ! N ~ L APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend _ Operation Shutdown _ Re-enter suspended well _ 2. Name of Operator ARCO Alaska. Inc. !3. Address I P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 1902' FNL, 1968' FEL, Sec. 8, T7N, R9W, SM At top of productive interval 1269' FNL, 1968' FEL, Sec. 8, T7N, R9W, SM At effective depth 1218' FNL, 1313' FEL, Sec. 8, T7N, R9W, SM At total depth 1213' FNLr 1308' FELt Sec. 8~ T7N~ R9W~ SM Alter casing _ Repair well _ Plugging _ Change approved program _ Pull tubing _ 5. Type of Well: Development X Exploratory _ Stratigraphic _ Time extension Stimulate Variance_ Perforate X Other_ 6. Datum elevation (DF or KB) KB = 155'. GL = 129' 7. Unit or Property name Soldotna Creek 8. Well number SCU 31-8 9. Permit number 81-00~ 10. APl number so-1 33-20344 11. Field/Pool Hemlock feet 12. Present well condition summary Total Depth: measured Effective depth: Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: 10616-1 0634', 10501-10519', true vertical measured true vertical Length 40' 3354' 10424' 656' measured 10664-10672', true vertical 10548-10556', Tubing (size, grade, and measured depth 3-1/2", 9.3#, J-55, to 10142', 10,904' MD feet Plugs (measured) 10,783' TVD' feet 10,904 - 10,860' 10,860' MD feet Junk (measured) 10,740' TVD feet Size Cemented Measured depth RECEIVED I 0- 3 / 4" 3354' MD 7- 5/8" MAY 0 9 ;1990 0452' MD 5- 1 / 2" 10902' MD AJaska Oil & Gas Cons, Commiss~otl ~nchorage 10695-10703', 1'0706-'10710', 10726-10732' True vertical depth 72' TVD 3354' TVD 10341' TVD 10781' TVD MD 10578-10586', 10589-10593', 10608-10614' TVD 2-7/8" 6.5# N-80 from 10142-10564'. Packers and SSSV (type and measured depth) Baker 7-5/8" DB ~ 10144'. 13. Attachments Description summary of proposal ~ Detailed operation program _ BOP sketch X 14. Estimated date for commencing operation 115. Status of well classification as: May. 1990 J ou x _ Gas _ 16. If proposal was verbally approved Name of approver Date approved Se, rv,ice .... 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~ ~J~3,,,..,. ' Title Cook Inlet Engineering Manager FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity_ BOP Test_ Location clearance__ Mechanical Integrity Test_ Subsequent form require 10-~'~ Suspended _ Date IIAppr°val No.~), Approved by the order of the Commission Form 10-403 Rev 5/03/89 ORIGINAL SIGNED BY LONNIE C. SMITH Approved Copy Returned Commissioner SUBMIT IN TRIPLICATE Well SCU 31-8 Obtective -- Perforate H6 Sand in order to increase oil production. Current Status SCU 31-8 is producing 225 BOPD @48,000 SCF/STB Last Tag Fill: 3-18-90 @ 10659' MD Pressures: FTP 1250 psi PC 1150 psi SC 100 psi Procedure · Prior tO Perforation 1. RU slickline and tag fl!l with 1.8" gauge ring. RD slickline. 2. Contact Anchorage o.O~ce to verify sundry approval before proceeding. · pcrforatin9 1. MIRU E-Line Unit. Pressure test lubricator to 4000 psi. 2. SI well. RIH w/ perf gun/CCL and magnetic decentra!tzers. Tie-in to perf the following intervals in I gun run: Run No, Interval* Footage Ift) Sand SPF 1 10593-10606 14 H6 4 * NOTE' Tie in log is the Cased Hole Compensated Neutron Log (7-28- 86). 4. Immediately after firing POOH. RD E-Line Unit. 5. Test well on days 1,3,5 and 7 following re-perforation. _Company Schlumberger Western Arias Gun Tvve Gun Size Enerjet Strip Silver Jet 1-11/16" i~AY o 9:19~0 Nas~ Oil & Gas Cons. Anchorage Well- SCU 31-8 Spud Date' 6/82 Original RKB: 155' Top of Hemlock: 10,440 Attachment #2 Completion Date: 10/82 Hanger Type: Gray Max. Hole Angle' 17° · ~/ell Type: Producer Last Workover: 4/14/89 Hanger' CWC-F6 Angle @ Hemlock- 14= All Depths are RKB MD to Top of Equipment. ikI NOTE: PBTD = TD = Jewelry 1 2119 2 10,068 3 10,109 4 10,144 5 10,531 6 10,564 Minimum ID: Camco 3-1/2" x I"KBUG GLM Meda 3-1/2' x 1-1/2" TPDX GLM Otis 3-1/2" 'X' Nipple Baker 7-5/8" x 3-1/2" 'DB' Packer I.D. 3.250 w/10' SBE Otis 2-7/8" 'XN' Nipple I.D. 2.205 Baker 2-7/8 Shear out Sub 2.205" (a) .10.531 (Otis 2-7/8" 'XN' lll_oOle} Casing and Tubing Size Weight Grade Description 20" 0 72' 10-3/4" 40.5#/fi K-55 0 3354' 7-5~8' 33.7 #/I1 S95 0 10,452' 26.4 #/ft N80 29.7 #/ft 5-1/2" 20 #/ft N80 10,246 10,902 Liner 3-1/2' 9.2# N80 0 1013' Tubing 3-1/2' 9.3# J-55 1013' 10142' Tubing 2-7/8" 6.58 N80 10,158' 10,564' Tubing Conductor Pipe Surface Casing Production Casing Perforation Data ~ Zone FT SPF Date Commertls 10,616 - 10,634 H8 18 4 5/10/83 2-1/8" DA Slimkone 6 8~4~86 3-3/8' Baker TCG 10,664 - 10,672 H8 8 4 5/10/83 2-1/8" DA Slimkone 6 8/4/86 3-3/8" Baker TCG 10.695 - 10,703 H8 8 4 5/10/83 2-1/8" DA Slimkone 6 8/4/86 3-3/8' Baker TCG 10,706 - 10,710 H8 4 4 5/10/83 2-1/8" DA Slirnkone 6 8/4/86 3-3/8" Baker TCG 10,726 - 10,732 H10 6 4 10/7/82 2-1/8" DA Slimkone 6 8/4/86 3-3/8" Baker TCG The Surface Casing annulus was used to downsqueze the liner lap during the 1986 workover of this well. 10,854' 10,904' Well SCU 31-8 By: JWR - 4727/88 Revised · JLB 5/8/89 (,,,,O' (o E-Line BOPE's Grease Head/ Hydraulic Packoff Lubricator Extension Manual Rams Swab Valve Double Master Valves Wellhead ARCO ALASKA INC. Cook Inlet/New Ventures Engineering TRANSMITTAL #343 TO:. John Boyle FROM: Tom Wellman 'COMPANY: AOGCC COMPANY: ARCO Alaska, Inc DATE: .... Aug. 22, 1989 .WELL NAME: Listed Below Transmitted herewith are the following Blue Sepia Sepia Line Folded'Rolled Mylar Tape Gamma Ray ..SCU 41-9A .... . 1 · . PLS SCU 41-9A 1 Vel'ffi. o~[ SCU 14-3 1 . Vertilog SCU 31-8 ! ,, , , ,, , , , , Receipt Acknowledgement: Remm reciept to ARCO ALASKA, Inc. ATrN: Judy Boegler ATO 1390A Post Office Box 100360 Anchorage, AK 99510-0360' Cons. lnchora , e STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION CO~MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Classification of Service Well 1. Status of Well OIL r~ GAS ~ SUSPENDED ~t NDONED ~ SERVICE I--1 ,,. 2. Name of Operator 7. Permit Number ARCO Alaska, I nc, 81-0099 3. Address 8. APl Number P.0. Box 100360, Anchorage, AK 99510-0360 5o- 133-20344 4. Location of well at surface 9. Unit or Lease Name 1902' FNL, 1968' FEL, Sec. 8, T7N, Rgw, SM Soldotna Creek Unit At Top Producing Interval 10. Well Number 1269' FNL, 1968' FEL, Sec. 8, T7N, Rgw, 5M 5CU 31-8 At Total Depth 11. Field and Pool 1213' FNL, 1308' FEL, Seco 8, T7N, Rgw, 5N Swanson River - Hemlock 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. KB=155' GL=129'I A-028996 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 116. No. of Completions 06/26/82 08/23/82 09/05/82*[ N/A feet MSLI 1 17. TotalDepth(MD+TVD) 18. Plug Back Depth (MD+TVD) 19. DirectionalSurvey I 20. Depth where SSSV set I 21. Thickness of Perrnafrost 10904'MD/10783'TVE 10860'MD/10740'TVD YES ~ NO [] N/A feet MD N/A 22. Type Electric or Other Logs Run DIL, BHCS, SP, CNL, SWC, DIL/SP/GR/BHC/Accoustilo.q/Cal/SP/GR,CDL/CNL/GR,CBL,CBL/VDL~ Single Shot svy, Yertilo¢ · 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 94.0# H-40 Surf 72' -- Driven ..... 10-3/4" 40.5# K-55 Su~'f ~R~,' 1/~-~/~," 1/~qO _~ Class O 7-5/8 .~_~_7/?R.b,/2~.7 .~-9C,/N-I{O ~,,rf 11~/~=,?' q-7/~" ~nn ~ rl~ r. 5-1/2" 20.0# N-80 102z;~' 10902' R-~/~" R~ ~ ~1~ (; Sqzd liner ~ ..... /~" _~× ¢!ass C , - . 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING ~ORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3-1/2"/2-7/8" 10564 ' 10144 ' Perforated w/4 spf 0° phasing .... 10616, _10634 'MD/10501 , _10519 'TVD 10664 '-10672 'MD/10548 '-10556 'TVD 26. ACI D, FRACTURE, CEMENT SQUEEZE, ETC. 10695'-10703'MD/10578'-10586'TVD DEPTH INTERVAL (MD) AMOUNT& KINDOF MATERIAL USED 10-3/4" x .7-5/8" an~ 850 sx Class G (lnr lap sqz) 10706 '-10710 'MD/10589 ' -10593 'TVD 10726 ' -10732/MD/10608 ' -10614 ' TVD . 27. N/A PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OI L-BBL GAS-MCF WATER-BBL CHOKE'SIZE GAS-OIL RATIO TEST PERIOD II~ Flow Tubing Casing Pressure CALCULATED,,~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl {corr) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or ware r. Submit core chips. * Note: Perforated well 10/7/82 and 5110183. Workover performed 4113189. ":/', 7' ;" ': t'~' t'~ , Submit in duplicate Form 10~107 041/WC6 Rev. 7-1-80 CONTINUED ON REVERSE SIDE MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. N/A N/A 32. I hereby certify that the foregoing is true and correct to the best of my knowledge 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 e~ch additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (D.F, 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". Form 10-407 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATId / 1. Operations performed: Operation shutdown m Stimulate __ Plugging __ Perforate ~ Workover 2. Name of Operator ARCO Alaska, Inc. Pull tubing ~ Alter casing __ Repair well 3. Address '"P';O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 1902' FNL, 1968' FEL, Sec. 8, T7N, RDW, SM At top of productive interval 1269' FNL, 1968' FEL, Sec. 8, T7N, RDW, SM At effective depth 1218' FNL, 1313' FEL, Sec. 8, T7N, R9W, SM At total depth 1213' FNL, 1308' FEL, Sec. 8, T7N, Rgw, SM 12. Present well condition sUmmary Total depth: measured true vertical 13. Effective depth: 5. Type of Well: Development _~_ Exploratory ~ Stratigraphic ~ Service ~ 14. Other ~ 6. Datum elevation (DF or KB) KB=155' GL=129' feet 7. Unit or Property name 5oldotna Creek Unit 8. Well number SCU 31-8 9. Permit number/approval number 81-0099/9-0os 10. APl number 50-- 133-20344 11. Field/Pool Swanson R i ver-Heml ock Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: 10904 'MD feet Plugs (measured) None feet 10783 'TVD measured 10860'MD true vertical 10740 'TVD feet Junk (measured) None feet Length Size Cemented Measured depth True vertical depth 40' 20" Driven 72 'MD 72 'TVD 3353' 10-3/4" 1490 sx Cl ass G 3383 'MD 3383 'TVD 10424' 7-5/8" 800 sx Cl ass G 10452'MD 10341 'TVD 656' 5-1/2" 86 sx Class G 10246'-10902'MD 10144'-10781'TVD measured true vertical 5qzd liner lap w/184 sx Class G and 850 sx Class G (in Ann.) 10616'-10634' 10664'-10672', 10695'-10703', 10706'-10710' 10726'-10732' , , 10501'-10519', 10548'-10556', 10578'-10586', 10589'-10593', 10608'-10614' Tubing (size. grade, and measured depth) 3-1/2"/2-7/8", N-80, tbg w/tail ~ 10564' Packers and SSSV (type and measured depth) SSSV: None, Baker 'DB' pkr @ 10144 Stimulation or cement squeeze summary N/A Intervals treated (measured) Treatment description including volumes used and final pressure N/A Representative Daily Average Production or Injection Data OiI-Bbl Gas-MCf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 15. Attachments 116. Status of well classification as: Copies of Logs and Surveys run ~ I Daily Report of Well Operations .-v- , Oil __.v Gas __ Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Service . Form 10-404 Rev 06/15/88 Title Area Drillinq Enqr, ( DAM ) SW04/033 Date · SUBMIT IN DUPLIOAIE ADDENDUM WELL: 2/24/87 2/25/87 4/02/89 31-8 (SWANSON RIVER) RU & tst lubr. RIH w/dummy rn, POH. RIH w/2-7/8" PKN plug to 10,458' & set, POH. RIH w/prong, POH. Bled tbg f/3650 psi to 0 psi; while bleeding, prod csg went f/500 psi to 0 psi, prod csg ann full of crude, tbg fluid level @ 10,261'. Tst tbg & csg packoffs to 5000 psi. Instl needle vlvs, service tree vlvs. Press prod csg to 2500 psi; no loss. Press tst tree vlvs to 5000 psi; all head. RIH w/pull tl, pull prong f/2-7/8" PXN plug body @ 10,458', POH. RIH w/pull tl, pull PXN body, RD WL. Turn well over to Production. RU Precision WL. Shift XA slv@ 10,130'. RU Halliburton. Circ well w/435 bbls 8.8 ppg brine. ARCO Oil and Gas Company Well History - Initial Report - Daily InslrueUene: Prepare and submit the "Htilill RiImlt' on the first Wednesday after a well is spudded or workover o~,~rations are star,ed. Daily work prior to spudding should be summarized on the fo~m giving inclusive dates only. District Field Au~.orW.O. no. ICounty. paris~ or borough TNT.RT/IL'2MAT I Leese or Unit Title ~b. DL .- &-O28996 Stat:w .~r'~ ~I-R Nell no. Operator Spudded or W.O. begun ~1Date I Date and depth Complete record for each day reported as of 8:00 a.m. 04/03/89 ( TD:10904 PB:10860 SUPV=DL 04/04/89 ( TD:10904 PB=10860 SUPV:DL 04/05/89 ( TD:10904 PB:10860 SUPV:DL 04/06/89 ( TD:10904 PB:10860 SUPV:EEV 04/07/89 ( TD=10904 ~B=10860 SUPV:EEV 04/08/89 ( TD:10904 PB:10860 SUPV:EEV 04/09/89 ( TD=10904 PB:10860 SUPV:EEV The above is correct I~or form prep~'~l~n and distribu{fl~,,, see Procedur~s_~lanual, Section 10, Drilling, Pages-B6 and 87. API: 50-133-20344 04/03/89 IH°ur 0900 'RR~ RIG UP MW: 0.0 MOVE RIG FROM 14-3. DAILY:S13,006 COM:$13,006 ETD:S13,006 EFC:$330,000 SET BPV MW: 9.1 BRINE RAISE DERRICK. PULL BPV R/U TO CIRC WELL. SITP 250 AND SICP 500. ACCEPT RIG ~ 0900 HRS, 4/4/89. CIRC OUT GAS WITH 8.8 PPG BRINE. MONITOR WELL. SMALL FLOW OUT OF ANNULUS AND TUBING. SITP 50. CIRC AND RAISE WEIGHT TO 9 PPG. SITP 25 PSI WITH SMALL FLOW OUT ANNULUS. CIRC AND RAISE WEIGHT TO 9.1 PPG. MONITOR WELL. WELL U-TUBING. ALLOW TO EQUILIZE. WELL STATIC. SET BPV. DAILY:S17,574 CUM:$30,580 ETD:S30,500 EFC:$330,080 POOH L/D 3.5" TUBING. MW: 9.3 BRINE N/D TREE AND N/U BOP. RAISE AND RIG UP DRILL FLOOR. SICP 400 PSI. BLEED OFF GAS. TEST BOP'S. CIRC OUT GAS AND RAISE WEIGHT TO 9.3 PPG. WELL STATIC. P/U ON TUBING. TUBING FREE. POOH L/D 3.5" TUBING. DAILY=S24,403 CUM:$54,983 ETD:SO EFC:$384,983 P/U 3'-~'/2" D.P. MW: 9.3 BRINE FINISH. POOH WITH TUBING. P/U 6-5/8" BIT 4-3/4" DRILL COLLARS AND RIH P/U DP ETD:S84,661 EFC:$330,080 MW: 9.3 BRINE CBU.CUT DRILL LINE. POOH. RIH TO TOL. CBU NO GAS. ETD:S109,369 EFC:$330,080 MW: 9.3 BRINE DAILY:S29,758 CUM:$84,741 POOH TO RUN CASING LOG P/U DP RIH. TAG TOL AT 10,237. HOLE NOT TAKING PROPER FILL UP. POOH TO RUN VERTILOG. DAILY:S24,708 CUM:$109,449 RIH WITH RBP POOH AND STAND BACK BHA. R/U DRESSER ATLAS RUN GR/JB TO TOL AT 10233 WLM. RUN VERTILOG FROM 10208 TO SURFACE. R/U AND P/U REP AND TIH. DAILY:S29,611 CUM:$139,060 ETD:S138,980 EFC:$330,080 POOH MW: 9.3 BRINE FINISH RIH WITH REP. SET RBP AT 10175. TESTED CASING TO 2500 PSI FOR 30 MIN. POLL 2 STANDS. RIH WITH 7-5/8" RTTS AND SSV VALVE. AND SET AT 23'.RKB. TEST STORM PKR' TO 500 PSI. BLEED PRESSURE OFF OF 10-3/4" X 7-5/8" ANNULUS. N/D BOP AND N/U AND TEST11"SM X 7-1/16" 5M FMC TUBING HEAD TO 3000 PSI. N/U AND TEST BOP'S. RIH AND RELEASE STORM PKR AND L/D SAME~Det~EE-TEST CASING~O~ 2500 PSI TO TEST SECONDARY IARCO W.I. 4R.a~R4 Prior status if a W.O. AR3B-459-1-D INumber all daily well history forms consecutively aa they are prepared for each well. iPage no. ARCO Oil and Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Filtal" form. 1} Submit 'llttertm" sheets when filled out but not less frequently than every 30 days, or on Wednesday of the week in which oil string is set. Submit weekly for workovere and following setting ot oil strin§ until completion. District ~County or Parish _ ] Stat~l~ ARCO ALASKA INC. I COOK INLET/KENAI Field ILease or Unit I SCU 31-8 SWANSON RIVER IWell no. Date and depth as of 8:00 a.m. 04/10/89 ( TD:10904 PB=10860 SUPV:EEV 04/11/89 ( TD:10904 PB:10860 SUPV:EEV 04/12/89 ( TD:10904 PB:10860 SUPV:EEV 04/13/89 ( TD:10904 PB:10860 SUPV:DL Complete record for each day while ~illing or workover in progress ROLL'N RIG PULL RBP. POOH WITH RBP. DAILY:S21,105 CUM:$160,165 ETD:S160,085 EFC:$330,080 CIRC MW: 9.3 BRINE FINISH POOH L/D 4-3/4" COLLARS. P/U 3-1/8" COLLARS WITH 4-5/8" BIT AND TIH. SET DOWN AT 10,658. RAN ON VERY HARD CAP FOR 2 HOURS. BROKE THROUGH. WASH AND REAM TO PBTD @ 10,838. CIRC OUT WITH 20 BBL HEC POLYMER SWEEP. DAILY:S21,412 CUM:$181,577 ETD:S181,497 EFC:$330,080 RUNNING 2-7/8" TAIL + PKR MW: 9.3 NaC1 PULL 10 STANDS TO TOP OF LINER. TIGHT AT 10,619'. OBSERVE WELL AND LET SAND FALL IN LINER. RIH TAG TOP OF FILL AT 10832 (6' OF FILL). CIRC AND FILTER. CUT DRILL LINE POOH. L/D COLLARS. R/U AND RUN 2-7/8" TUBING ASSY. DAILY:S20,392 CUM:$201,969 ETD:$201,899 EFC:$330,070 POOH L/D DRILL PIPE MW: 9.3 NaCl P/U PKR AND RIH ON DRILL PIPE. DROP BALL AND SET PKR AT 10,121' SHEAR OUT BALL AND TEST BACK SIDE TO 2500 PSI-OK. RELEASE FROM PKR. POOH L/D DP. DAILY:S16,716 CUM:$218,685 ETD:$218,605 EFC:$330,080 SPACE OUT COMPL MW: 9.3 NaC1 FINISH POOH L/D DRILL PIPE. R/U AND RUN 3-1/2" COMPLETION ASSY. LOCATE INTO PACKER AND SPACE OUT TUBING. (SSSV: NONE, BAKER 'DB' PKR @ 10144', TT @ 10564') DAILY:S74,791 CUM:$293,476 ETD:S293,396 EFC:$330,080 The above is correct For form prepa~i~e'n and distrib~:h see Procedure~..Wlanual Section 10, Drilling, Pages 86 and 87 Drilling Supt. ~ AR3B-459-2-B INumber all daily well history forms consecutively as they are prepared for each well. IPage no. ARCO Oil and Gas Company Daily Well History-Final Report instructions: Prepare and submit the "Final ReDort" on the first Wednesday after allowable has been assigned or well is Plugged. Abandoned. or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not recluired upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. Accounting cost center code District County or Parish State ARCO ALASKA INC. I COOK INLET/KENAI Field Lease or Unit SWANSON RIVER ADL: A-028996 Auth. or W.O. no. little AD 6374 I WORKOVER A~I: 50-133-20344 Operator I A.R.Co. W.I. ARCO 48. 4864 Spudded or W.O. begun ~Date ACCEPT I 04/03/89 complete record for each day reported ROLL'N RIG 5 Date and depth as of 8:00 a.m. did TD Released rig 04/14/89 TDtl0904 PB=10860 SUPV:DL Classifications (oil, gas, etc.) SCU 31-8 Iwel, .o. Iotal number of wells (active or inactive) on this dst center prior to plugging and ~ bandonment of this well I our IPrior status if a W.O. I 0900 HRS RIG RELEASED MW: 9.3 NaC1 SERV RIG. SPACE OUT AND LAND TBG. DROP BALL AND LET FALL. TEST TBG TO 2500 PSI. TEST ANN TO 2500 PSI. TIW VALVE WOULD NOT OPEN. PULL OUT OF PKR. CHANGE OUT TIW VALVES. RELAND TBG. RETEST TBG TO 2500 PSI. SHEAR BALL AT 3000 PSI. SET BPV. ND BOPE. NU TREE. TEST TREE & PACK OFF TO 5000 PSI. SET BPV. RELEASE RIG AT 22=30 HRS, 04/13/89. DAILY=S26,117 CUM:$319,593 ETD:S319,593 EFC:$330,000 New TD pB Depth Date I Kind of rig Type completion (single, dual, etc.) Producing method Official reservoir name(s) Potential test data Well no. Date Reservoir Producing Interval Oil or gasTest time Production Oil on test Gas per day Pump size, SPM X length I Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct · ,"", . Datl//// ITM Signature ~ ~ I /~/~ Drilling Supt. sFe°; fl~;o~ePdruerPe~ral~ia°nnu n,~sdeiSc~ir~nbU~i0°,n' ~ Drilling, Pages 86 and 87, AR3B-459-3-C Number all daily well history forms consecutively as they are prepared for each well. jPage no. Division of AtlantlcRIchfleldCompm STATE OF ALASKA MI~..,~ON A&,.,KA OIL AND GAS CONSERVATION COM APPLI TION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ Alter 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 ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, AK 99510-0360 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at sudace 1902' FNL, 1968' FEL, Sec. 8, T7N, Rgw, SM At top of productive interval 1269' FNL, 1968' FEL, Sec. 8, T7N, Rgw, SM At effective depth 1218' FNL, 1313' FEL, Sec. 8, T7N, Rgw, 5N At total depth 1213' FNL, 1308' FEL, 5ac. 8, T7N, Rgw, SM 6. Datum elevation (DF or KB) KB=155 ' GL=129' 7. Unit or Property name Sol dotna Creek 8. Well number 31-8 9. Permit number 81-0099 10. APl number 50-- 133- 20344 11. Field/Pool ,~,-^~w,-~ Hemlock 12. Present well condition summary Total depth: measured true vertical 10904 'MD 10783 'TVD feet feet Plugs (measured) 10904-10860 Effective depth: measured 10860 'MD true vertical 10740 'T ~) feet feet Junk (measured) None 13. Casing Length Size Structural Conductor 40 ' 20" Sudace 3353 ' 10-3/4" Intermediate 10424 ' 7 -5/8" 656' 5-1/2" Production Liner Perforation depth: measured Cemented 10616'-10634', 10664 '-10672 ', 10695 '-10703 ', 10706'-10710 ', 10726'-10732 ' true vertical 10501 ' -10519 ', 10548 ' -10556 ', 10578 ' -10586 ', 10589 ' -10593 ', 10608 ' -10614 ' Tubing (size, grade, and measured depth) 3-1/2", 9.3#, N-80, to 10181', 2-7/8" 6.5# N-80 from 10181'-10154' Packers and SSSV (type and measured depth) Baker 7-~/R" FHi (~ 1017zr, F.C,T RHP - R.R nnn F'MW Attachments Measured de pth 72'MD 3383 'MD 10452 'MD 10902 ' MD True vertical depth 72'TVD 3383 'TVD 10341 'TVD 10781 ' TVD Description summary of propo's~i'.z,_ feet Detailed operations program BOP sketch -X-. 14. Estimated date for commencing operation 115. Status of well classification as: February 1, 1989 16. If proposal was verbally approved Oil ~ Gas Suspended Name of approver Date approved Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Date Signed I Approval No. ¢ ~ ~ 0,.~ Date Title Area Dri 11 i ng 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- z/~r.~ Approved Copy Returned ORIGINAL SIGNED BY /- ¢'"- ~,¢ Approved by order of the CommissionL~rNNIE C. SMITH __Commissioner Form 10-403 Rev 06/15/88 042/$A4 SUBMIT IN TRIPLICATE SRU 31-8 GENERAL PROCEDLRE pRE-RIG ARRIVAL 1. Kill well with produced water, pumping kill pills as neccesary. 2. Chase threads in BPV profile. RIG OPERATIONS 1. MIRU Roll'n 5. Establish circulation to ensure well is dead. ND tree. NU BOPS & test same. 2. Release Baker FHL packer(if not already released). Circulate BU. POH LD tbg, 3. Make a 6-5/8" bit and scraper run to TOL @ 10246'. Circ bottoms up 4. GIH with a retr, BP. Set same at 10175' and test csg. PU a storm pkr, set same 1' below tbg.spool. Rel from pkr. 5. Change out tbg spool. NU and test BOPS. Retr. pkr and BP. 6. Make a 4-5/8" bit and scraper run and clean out fill to TD @ 10854'. Circ hole clean. 7. PC~ and LDDP. 8. Run a new 3-1/2"completion with 2-7/8" tailpipe below the packer, Set the packer in the 7-5/8" and run enough tailpipe to put the tbg tail +/-75' above the top perf in the 5-1/2" liner. 9. Release Rig. Displace the well to lease crude after the rig is moved off. . $¢U ,.~puO Oite: 6182 Original RKB: 155' ?op o! Homloak: 10,440 APlI: )repletion Dele: 10/82 flanger Typo: gray MIX. Hole Anglo: 17' AJI Dopthe ere RKB MO to Top of Equipment. Wdl Tylx: Pfodu~r Lilt Workover: ~ Hanger: CW~,-F0 Angle Il) Hemlock: 14' · Jewelry , l 6 NOTE: PBTD · TO· 8004 t0,180 10.1# 10.174 S 10,4Bi 0 10.S84 Mlfl~num 0I 8-14p'x'NIpple 0i o.1/r'x# 8loov~ Brown 0.14' CC 8dety Jobqt Be;ar Y44' x HA' PHI. pEkor W 8-14' x 8-74' OrNI0VW tolerant b · 1OJid* MD Muds workoverb (hllnl IMI Tublnl ~ Ill DIICdotlOll 80' 0 ?r ~,ofldu~x P# 10-3/4" 40.St~I K-SS 0 8384' 8udlOl ~ ?-8/r 08.71~ 80S 0 -10,#r PmduadonC,~ 86.4 dMt NS0 lO.? Mt 8-1/~ I0 I/il NI0 10.140 10J01 Liner tM NI0 0 10.t01' Tubing Ltd Nl0 10.181'10.144 Tdd~ ~ Zone PT ~PF I)lll Comments , 10Jlt · 1U04 Ht 18 4 S/10/83t-l~' DA S,ffiMw 0 8/4/80 ~ Biker TP.~ 10,~4- 10,r/t H~ ~ 4 5/10~ J-14' DA ~~ 10.~ - 10,~ ~ 8 4 ~10~3 8-1~ DA ~~ e 8/4me ~ B~ T~ 10.~ · 10.710 ~ 4 4 S/10~ 8-14' DA ~~ 6 81~6 ~' B~r T~ 10,7~ - 10.7~ HI0 0 4 10/7/O E-I~' DA ~lirtloI~ 0 8/4/80 ~ Biker TC, G 1000 wodmver of thai wol. 10.8S4' 10.004' 31-8 ANNULAR PREVENTER 7 PIPE RAILS 6 BLINO RAMS ) 3 1. /o-~/f'' SURFACE CASING 2. ~ CASINO HEAD /i "- 5 000 PSI FLANGE 3 ~l ,, _5000 PSI X 9''~ SO00 PSi TUB lNG HEAD 4. ~ "- $000 PSI X 11" - 5000 PSI CROSS-OVER SPOOL. S. i 1" -$000 PSi BLIND RAMS 6. 11" - $000 PSI PIPE RAMS ?. 11"- $000 PSI ANNULAR ACCUMULATOR CAPACITy TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. A&$URE THAT ACCUMULATOR PRE~,~URE I~ ~000 P,.,e,I WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS,SIMULTANEOU,SLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE lAD(; REPORT. THE ACCEPTABLE LOWER LIMIT' IS 4,~ SECONDS CLOSING TIME AND 1200 PS1 REMAINING PRESSURE. JAF.~ u '~ )9~g BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH BRINEAia$1~-Oii-&. ~s Coa~.Cornml~s~.,~. 2. CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY"RE~~ PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN 5C::REW$ IN HEAD. 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. 4. TEST ALL COMPONENTS TO 250 PS1 AND HOLD FOR 10 MINUTES. 5. INCREASE PRES,SURE TO 1800 PSI AND HOLD FOR 10 MINUTES. BLEED TO ZERO PSI. 6. OPEN ANNULAR PREVENTER AND CLOSE PIPE RAMS. 7. INCREASE PRESSURE TO 5000 PSi AND HOLD FOR 10 MINUTES. 8. CLOSE YALVE$ DIRECTLY UPSTREAM OF CHOKES. BLEED DOWN,STREAM PRES,SURE TO ZERO PSI TO TEST VALVES. TEST REMAINING UNTESTED MANIFOLD VALVES, IF ANY, WITH $000 PSI UPSTREAM OF VALVE AND WITH ZERO PSI DOWNSTREAM. BLEED SYSTEM TO ZERO PS1. 9, OPEN PIPE RAMS. BACKOFF RUNNINGUOINT AND PULL OUT OF HOLE. CLC:k$E BLIND RAMS AND TEST TO 5000 PS1 FOR 10 MINUTE8, BLEED TO ZERO PSI. 10. OPEN BLIND RAMS AND RECOVER TEST PLUG, MAKE SURE MANIFOLD AND LINE5 ARE FULL OF BRINE AND ALL VALVES ARE SET IN THE DRILLING POSITION. 11. TEST STANDPIPE VALVES TO 5000 PS1. 12. TEST KELLY COCKS AND INSIDE BOP TO 5000 P$1 WITH KOOMEY PUHP 1 ~. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. DM MARCH 9, 1987 . STATE OF ALASKA ALAS OIL AND GAS CONSERVATION COM ,,~SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon ~ Suspend [] Operation Shutdown [] Re-enter suspended well ~ Alter casing ~ Time extension ~ Change approved program [] Plugging [] Stimulate ~ Pull tubing ~ Amend order E~ Perforate ~ Other 2. Name of Operator ARCO Alaska, Inc. 3. Address Post Of 4. Location fice Box 100360 of well at surface 5. Datum elevation (DF or KB) 155' KB Anchorage, AK 99510 1902' S & 1968' W of NE corner, Sec. 8, T7N, R9W, SB&M Attop of productiveinte~al 1269' S & 1968' W of NE corner, Sec. 8, T7N, R9W, SB&M 6. Unit or Property name Soldotna Creek Unit 7. Well number At total depth 1213' S & 1308' W of NF ~c~rn~.r; .c;~r: R. T7N. ~_qw. _q~&U 11. Present well condition summary Total depth: measured 10,904 ' feet Plugs (measured) true vertical 10,783 ' feet Effective depth: measured 10,854 ' feet Junk (measured) true vertical 10,734 ' feet Casing Length Size Cemented Surface 74 ' 20" dr i yen Intermediate 3383' 10-3/4" 1490 SKS Production 10452' 7-5/8" 872 SKS Liner 656 ' 5-1/2" 86 SKS Perforation depth: 10,616-10,634'; 10,664-10,672'; 10,695,-10,703'; SCU 31-8 8. Permit number 9. APl number 50-- 133-2034-00 10. Pool Swanson River - Hem lock Tubing (size, grade and measured depth) feet none none Measured depth 0-74' 0-3383' 0-10452' 10246-10902' Wue Verticaldepth 0-74' 0-3383' 0-10342' 10143-10782' 10,706-10,710'; 10,726-10,732' RECEIVED Form 10-403 Rev 12-1-85 L0,,,, C. Approved by '~"' Conditions of approval Notify commission so representative may witness [] Plug integrity [] BOP Test [] Location clearance App,oved Copy Returned Commissipner Approval No. ~ ~'7 by order of the commission Date Submit in triplicate 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~.~2_ ~ Title Cook Inlet Engineering Manager /.,,,. - Commission Use OnlY May 18, 1988 14. If propOsal was verbally approved Name of approver Date approved 13. Estimated date for commencing operation 3-1/2", 9.3#, N-80, 0-10,181'; 2-7/8", 6.5#, N-80, 10 181-10 584' Packers and SSSV (type and measUred depth) ' ' :l ~ 1988 3-1/2" Baker, 7-5/8 x 3- 1/2 FHL Pkr ~ 10 174 ' ~,~.~. na ~, Ra~ P..n_q~ P. nmmi.~.~k 12.Attachments Description summary of proposal ~q Detailed operations program'-~ BOP S~fltihtlr~e Arc .laska Inc.- Swanson Rive( ,=ield Well- SCU 31-8 APl#: 133-20344-00 Well Type:Producer Spud Date' 6/82 Completion Date: 10/82 Last Workover: 8/86 Original RKB: 155' Hanger Type: Gray Hanger- CWC-F6 Top of Hemlock: 10,440 Max. Hole Angle: 17° Angle @ Hemlock- 14° All Depths are RKB MD to Top of Equipment. NOTE: PBTD = TD = Jewelry I 2004 2 10,130 3 10,162 4 10,174 5 10,458 6 10,584 Minimum ID: Fill Tao: Otis 3-1/2" 'X' Nipple Otis 3-1/2" 'XA' Sleeve Brown 3-1/2" CC Safety Joint Baker 7-5/8" x 3-1/2" FHL packer w/3-1/2" x 2-7/8" crossover Otis 2-7/8" 'XN' Nipple Shear out Sub 2.205" ~ 10.458 (Otis 2-71~" 'XN' nipple) 10.854' MD (during workover) Casing and Tubing Size Welaht Grade Too Bottom -- _ Descri0tipn 20" 0 72' 10-3/4"" 40.5#/ft K-55 0 3354' 7-5/8" 33.7 #/ft S95 0 10,452' 26.4 #/ft N80 29.7 #/ft 5-1/2" 20 #/ft N80 10,246 10,902 Liner Conductor Pipe Surface Casing Production Casing 3-1/2" 9.38 N80 0 10,181' Tubing 2-7/8" 6.58 N80 10,181' 10,584 Tubing Perforation Data Interval Zone FT ~PF Date Comment; 10,616 - 10,634 H8 18 4 5/10/83 2-1/8" DA Slimkone 6 8/4/86 3-3/8" Baker TCG 10,664 - 10,672 H8 8 4 5/10/83 2-1/8" DA Slimkone 6 8/4/86 3-3/8" Baker TCG 10,695 - 10,703 H8 8 4 5/10/83 2-1/8" DA Slimkone 6 8/4/86 3-3/8" Baker TCG 10,706 - 10,710 H8 4 4 5/10/83 2-1/8" DA Slimkone 6 8/4/86 3-3/8" Baker TCG 10,726 - 10,732 H10 6 4 10/7/82 2-1/8" DA Slimkone 6 8/4/86 3-3/8" Baker TCG The Sudace Casing annulus was used to downsqueze the liner lap during the 1986 workover of this well. 10,854' 10,904' Well RECEIVEI) SCU 31-8 MAY i 8 !988 By: JWR- 4/27/88 Alaska 0ii & Gas Cons. Commission Anchorage SCU 31-8 Add HIO Sand Perforations Procedure 1.) 2.) 3.) MIRU Slickline unit. PT lubricator to 3500 psi. RIH with a 2.0" gauge ring to PBTD. Tag 2-7/8" XN nipple and tubing tail for depth reference. POOH with gauge ring. RDMO slickline unit. Conduct an 8-hour guage to establish a baseline rate for SCU 31-8. 5.) 6.) 7.) 8.) 9.) 10.) 11.) Sundries have been submitted to the AOGCC and the BLM. Do not proceed with steps# 5 . 9 until notified by Anchorage Engineering that these sundries have been approved. MIRU E-line unit. SI well. PT lubricator to 3500 psi. RIH with perforating gun assembly to +10,740' MD. Open well to production on a 48/64" choke into the 150g production system. Let well stabilize for approximately 30 minutes. Tie in perforating guns with CBL dated 9/3/82 (attached) and position gun to perforate 10,732- 10,742' MD. .. Perforate the casing with 2-1/8" hollow carder perforating guns from 10,732' to 10, 742 'MD. The guns should be loaded 4 SPF, 0° phasing. After approximately 15 minutes, shut in well and POOH with E-line. RDMO E-line unit. Return SCU 31-8 to production in 150g production system and guage well on days #1, 2, 5, and 7. Choke setting should not be changed from its current setting of 48/64" unless absolutely necessary. RECEIVED MAY 1 ~ 19~8 Alaska Oil & Gas Cons. Commission Anchorage E-Line BOPE's Grease Head/ Hydraulic Packoff -,---- Lubricator Extension L Manual Rams Swab Valve Double Master Valves Wellhead RECEIVED MAY 1 $1988 Alaska Oil & Gas Cons. Commission Anchorage AR~O Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4724 David S. Joiner Engineering Manager Cook Inlet/New Ventures May 13, 1988 Mr. C. V. Chatterton, Chairman Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 RE: Sundry Notice for SCU 31-8 Dear Mr. Chatterton: Attached is an Application for Sundry Approval to perforate the casing in Well SCU 31-8. We propose to perforate the H10 interval from 10,732' to 10,742' MD with 2-1/8' hollow carrier perforating guns loaded 4 SPF. With your approval, we would like to begin this work as soon as possible. If you have any questions, please contact Tom Wellman at 263-4304. Sincerely, D. S. Joiner DSJ:JWR:ch:0006 Attachments RECEIYEI) MAY 1 Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany 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 ~ Alter casing ~ Time extension .m. Change approved program [] Plugging [] Stimulate [] Pull tubing E Amend order C Perforate ~ Other 2. Name of Operator 5. Datum elevation(DF or KB) ARCO Alaska, Inc. 155' KB feet 3. Address 6. UnitorProperty name Post Office Box 100360 Anchorage, AK 99510 Soldotna Creek Unit 4. Location of well at surface 1902' S & 1968' W of NE corner, Sec. 8, T7N, Rgw, SB&M At top of productive interval 1269' S & 1968' W of NE corner, Sec. 8, T7N, R9W, SB&M At total depth 1213' S & 1308' W 11. Present well condition summary Total depth: measured 10,904 ' true vertical 10,783 ' 7. Well number SCU 31-8 8. Permit number 9. APl number 50-- 133-2034-00 10. Pool Swanson River - Hemlock feet Plugs (measured) feet none Effective depth: measured 10,854 ' feet Junk (measured) true vertical 10,734 ' feet none Casing Length Size Cemented Measured depth ~]~,~'r Surface 74 ' 20" dr i ven 0-74 ' Intermediate 3383' 10-3/4" 1490 SKS 0-3383' Production 10452' 7-5/8" 872 SKS 0-10452' Liner 656 ' 5- 1/2" 86 SKS 10246-10902' Perforation depth: 10,616-10,634'; 10,664-10,672'; 10,695-10,703'; 10,706-10,710'; 10,.726-10,732' Rue Verticaldepth 0-74' 0-3383' 0-10342' 10143-10782' Tubing (size, grade and measured depth) 3-1/2", 9.3#, N-80, 0-10,181'; 2-7/8", 6.5#, N-80, 10,181-10,584' Packers and SSSV (type and measured depth) 3-1/2" Bakert 7-5/8 x ~-1/2 FHL Pkr ~ 10.174' 12.Attachments Description summary of proposal ~ Detailed operations program ~ BOP sketch 13. Estimated date for commencing operation ~" ~ ~'~-"" ~' ~' May 18, 1988 14. If proposal was verbally Name of approver 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~..~,~;;). ~.~ Title Cook Inlet Engineering Manager 'Commission Use Only Conditions of approval Notify commission so representative may witness I Approval No. [] Plug integrity [] BOP Test ~,' Location clearanceI ORIGINAL SIGNED BY Approved Copy Returned Approved by Date LONNiE C~ 'SMITH Commissioner by order of the commission Form 10-403 Rev 12.1-85 Submit in triplicate Well- scu 31-8 Spud Date: 6/82 Original RKB: 155' Top of Hemlock: 10,440 Arc~ Alaska Inc.- Swanson APl#: 133-20344-00 Completion Date: 10/82 Hanger Type: Gray Max. Hole Angle: 17° R iv(= r Field Well Type: Producer Last Workover: 8/86 Hanger: CWC-F6 Angle @ Hemlock: 14° All Depths are RKB MD to Top of Equipment. 3 NOTE: PBTD = TD = Jewelry I 2004 2 10,130 3 10,162 4 10,174 5 10,458 6 10,584 Minlmum ID: Otis 3-1/2" 'X' Nipple Otis 3-1/2" 'XA' Sleeve Brown 3-1/2" CC Safety Joint Baker 7-5/8" x 3-1/2" FHL packer w/3-1/2" x 2-7/8" crossover Otis 2-7/8" 'XN' Nipple Shear out Sub MAY Oil & 6as Cons. A~chorage 2.205" (a) 10.4~8 fOils 2-7/8" 'XN' 10.854' MD (durlna Workover) Casing and Tubing Size ~ Grade ~ Bottom Description 20" 0 72' 10-3/4"" 40.54rift K-55 0 3354' 7-5/8" 33.7 #/ft S95 0 10,452' 26.4 #/ft N80 29.7 #/ft 5-1/2" 20 #/ft N80 10,246 10,902 3-1/2" 9.3# N80 0 10,181' 2-7/8" 6.5# N80 10,181' 10,584 Conductor Pipe Surface Casing Production Casing Liner Tubing Tubing Perforation Data Interval Zone FT ~PF Date Comments 10,616 - 10,634 H8 18 4 5/10/83 6 8/4/86 10,664 - 10,672 H8 8 4 5/10/83 6 8/4/86 10,695 - 10,703 H8 8 4 5/10/83 ,6 8/4/86 10,706 - 10,710 H8 4 4 5/10/83 6 8/4/86 2-1/8" DA Slimkone 3-3/8" Baker TCG 2-1/8" DA Slimkone 3-3/8" Baker TCG 2-1/8" DA Slimkone 3-3/8" Baker TCG 2-1/8" DA $1imkone 3-3/8" Baker TCG 10,726 - 10,732 H10 6 4 10/7/82 2-1/8" DA Slimkone 6 8/4/86 3-3/8" Baker TCG The Sudace Casing annulus was used to downsqueze the liner lap during the 1986 workover of this well. 10,854' 10,904' Well SCU 31-8 By: JWR- 4/27/88 SCU 31.8 Add H10 Sand Perforations Procedure 1.) 3.) MIRU Slickline unit. PT lubricator to 3500 psi. RH-I with a 2.0" gauge ring to PBTD. Tag 2-7/8" XN nipple and robing tail for depth reference. POOH with gauge ring. RI)MO slickline unit. Conduct an 8-hour guage to establish a baseline rate for SCU 31-8. 5.) 6.) 7.) 8.) 9.) 10.) 11.) Sundries have been submitted to the AOGCC and the BLM. Do not proceed with steps# $ - 9 until notified by Anchorage Engineering that these sundries have been approved. MIRU E-line unit. SI well. PT lubricator to 3500 psi. RIH with perforating gun assembly to +10,740' MD. Open well to production on a 48/64" choke into the 150g production system. Let well stabilize for approximately 30 minutes. Tie in perforating guns with CBL dated 9/3/82 (attached) and position gun to perforate 10,732- 10,742' MD. Perforate the casing with 2-1/8" hollow carder perforating guns from 10,732' to 10, 742 'MD. The guns should be lOaded 4 SPF, 0° phasing. After approximately 15 minutes, shut in well and POOH with E-line. RDMO E-line unit. Return SCU 31-8 to production in 150~ production system and guage well on days #1, 2, 5, and 7. Choke setting should not be changed from its current setting of 48/64" unless absolutely necessary. MAY ! 8 19~-8 Alaska Oil & 6as 6ohs. 6ommissioB ~chorage E-Line BOPE's Grease Head/ Hydraulic Packoff Lubricator Extension REEEIVED MAY 1 8 1988 Alaska Oil & Gas Cons. CommisslOtl Anchorage L Manual Rams Swab Valve Double Mastex Valves Wellhead Chevron Chevron U.S.A. Inc. 6001 Bollinger Canyon Road, San Ramon, California Mail Address: P.O. Box 5043, San Ramon, CA 94583-0943 J. E Coltart Manager Non-Operated Joint Ventures Production Department Western Region June 9, 1987 Mr. L. C. Smith, Commissioner Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-3192 Dear Mr. Smith: Please find attached the workover completion report for well SCU 31-8, Soldotna Creek Unit. The report was inadvertently overlooked due to our Anchorage office closure and transfer of operations during October 1986. JGB:skw Attachment Very truly yours, cc: ARCO Alaska Inc. Mr. J. C. Havard P. O. Box 100360 Anchorage, AK 99510 UNOCAL Oil and Gas Division Mr. G. A. Graham P. O. Box 6247 Anchorage, AK 99502 Marathon Oil Company Mr. D. L. Jones P. O. Box 102380 Anchorage, AK 99510 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION ~ON1MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL I~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of' Operator 7. Permit Number Chevron U.S.A. [nc. 81-0099 -- 3. Address 8. APl Number P.O. Box. 107839, Anchorage, AK 99510 5o-133-20344 4. Location of well at surface 9. Unit or Lease Name 1902'5 & 1968'W of NE Corner Sec. 8, T7N,R9W, SB&M Soldatna Creek Unit At Top Producing Interval 10. Well Number 1269'S & 1968'W of NE Corner Sec. 8, T7N,R9W, SB&M SCU 31-8 ._. At Total Depth 1 1. Field and Pool 1213'S & 1308'W of NE Corner Sec. 8, 7TN,R9W, SB&M Swanson River 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. G.L.=129' K.B.=155'I A-028997 Hemlock , 12. Date SpuddedE/26/82 13. Date T.D. Reached8/,23/82 14' Date C°mp" Susp' °r Aband' 115' Water Depth' if °ffsh°re 116' N°' °f C°mpleti°ns. 8/9/86 NA , feet MSL one 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost Z0904'MD,10783'TVD 1085E'MD,ZO734'lV~B[~ NO[]I 10162 feetMDNA, 22. Type Electric or Other Logs Run GR-Neutron-CCL, GE .... 23. CASING, LINER AND CEMENTING RECORD ........ SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED ............. 20" Cond. Surf. 72' ........... 10 3/4" 40.5 K-55 Surf. 3383' 14 3/4'! 1490 SKS ..- 7 5/8" Surf. ]0452' 9 7/8" RO0 SKS , 5~" 20 N-801 10246' 10902' 6 5/8" 86 SK$ I , , ~4] Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECERD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) , , , 10616 ' - 10634, 10664' - 10672' 3~" 10584' 1 tl 174' 10695'-10703', 10706'-10710' (Lower 13 JTS are 2 7/R" TBG) 10726'-10732' (W/4½" JSPF) 26. ACID, FRACTURE, CEMENT SQU~EZE,'ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL uSED Wireli'ne MD. , .. SQZI. D LNR LAP 19 BBL Of Class.'G'...CMT · . ~@ 10246' (TOL) , .:. 27. PRODUCTION TEST , Date First Production Metl~od of Operation (Flowing, gas lift, etc.) 8/15/86 Flowing " Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF 'WATER-BBL' CHOKE Size IGAS-OILRAT10 TEST PERIOD m~I ,, "F/ow Tl~bilng Casing P'ressu're CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) iPress;...2250 175 24-HOUR RATE ]1~ 71 3099 3 41.. 1 28. CORE DATA · , Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. .......... Form 10-407 Submit in duplicate ~,~j Rev. 7-1-80 CONTINUED ON REVERSE SIDE , 29. NAME GEOLOGIC MARKERS II MEAS. DEPTI-I TRUE VERT. DEPTH GOR, and time of each phase. 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~.-~' ~'/ -~/~~/'~ Title 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 referer)ce (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. Subm,;i;~ a separate form for each additional interval to be separ3tely produced, sh~owing 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". Form 10-407 A ..KA OIL AND GAS CONSERVATION C ,,MISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] Perforate [] Pull tubing [] Alter Casing [] Other [] 2. Name of Operator 5. Datum elevation (DF or KB) Chevron U.S.A. Inc. G.L.=129' K.B.=155' Feet 3. Address 6. Unit or Property name P.O. Box 107839, Anchorage, AK 99510 Soldatna Creek Unit 4. Location of well at surface 1902'5 & 1968'W of NE Corner Sec. 8, T7N,R9W, SB&M At top of productive interval · 1269'5 & 1968'W of NE Corner Sec. 8, TTN,P,9W, SB&M At effective depth 1218'S & 1313'W of NE Corner Sec. 8, T7N,RgW, SB&M At total depth 1213'S & 1308'W of NE Corner Sec. 8~ T7N~R9W~ SB&M 11. Present well condition summary Total depth: measured true vertical · Effective depth: measured true vertical 7. Well number SCU 31-8 8. Approval number 81-0099 9. APl number 50-- 1 ~-?ll~4Zt 10. Pool Hemlock 10904 feet Plugs (measured) 10783 feet 10854 feet Junk (measured) 10734 feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor 40' 20" - 72' 72' Surface 3353' 10 3/4" 1490 SKS 3383' 3383' Intermediate 10424' 7 5/8" 872 SKS 10452' 10341' Production Liner 656' 5½" 86 SKS 10902' 10781' Perforation depth: measured 10616'-10634', true vertical NA Tubing (size, grade and measured depth) Single string Landed @ 10584': 13JTS 2 7/8" N-80; 330 JTS 3 - ½" N-80 Packers and SSSV (type and measured depth) Baker~. 7-5/8" x 3½~'' 'FHL'"'~PKR @ 10174'~ Brown 3~" ' 12. stimulation or cement squeeze summary SQZ'D Liner Lap @ 10246' (TOL). Intervals treated (measured) cc' Safety JT @ 10162'; Treatment description including volumes used and final pressure 19 BBL of Class 'G' CMT, Disolaced CMT w/salt water (Press. 42S~O#-50F)ll,~ @ 1/3 BPM) 13. Representative Daily Ave.rage Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 71 3099 3 175 2250 14. Attachments Daily Report of Well Operations [] Copies of Logs and Surveys Run [] 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed /~~~~ Title Date Submit in D~plic'ate Form 10-404 Rev. 12-1-85 WORKOVER COMPLEI"TON REPORT SMANSO# RIVER FTELD, ALASICA, Unit Name- Soldotna Creek Unit Lease No.' A-028997 Well No.' SCU 31-8 Surface Location' 1902'S & 1968'W of NE Corner Section 8, T7N,R9W, SB&M. Drilling Rig' Brinkerhoff Signal Inc. Rig #16 Rig Released: August 9, 1986 Rig Acceptance' July 24, 1986 Elevation: G.L.=129' K.B.=155' Total Depth- 10904' MD,10783' TVD Casing: Tubing' Plug Back Depth- 10854'MD,10734'TVD 20" conductor at 72' 10 3/4" cemented at 3383' 7 5/8" cemented at 10452' 5½" liner cemented 10246'-10902' 3½" tubing at 10584' (Lower 13 JTS are 2 7/8" TBG) Packers- 10174' Perforations- 10616'-10634', 10664'-10672', 10695'-10703', 10706'-10710', 10726'-10732' (W/4 ½" JSPF) Wi rel i ne MD. Logs Run: Gearhart GR-Neutron-CCL GR 7/24/86 7/25/86 7/26/86 7/27/86 7/28/86 7/29/86 7/30/86 7/31/86 8/1/86 8/2/86 8/3/86 8/4/86 SCU 31-8 MW:lO.2 MD: 10904' CSG: 7 5/8" @ 10452' RIG ACCEPTED @ 1800 HRS 7/24/86. ATTEMPTED TO KILL WELL WITH 10.2 PPG KILL MUD. CHOKE MANIFOLD HEADER BLEW IN TWO, DAMAGING CHOKE HOUSE. SHUT DOWN @ 0100 HRS FOR REPAIRS. VERBAL APPROVAL FOR WORKOVER RECEIVED FROM ADEN SEIDLITS W/BLM ON 7/21/86. MW:lO.2 MADE 2½ COMPLETE CIRCS W/10.2 PPG KILL FLUID - WELL DEAD. N/D TREE. MW:lO.2 N/D TREE. N/U & TEST BOPE. RECOVERED 3½" PRODUCTION TBG. RELEASED PKR & MW:lO.1 FINISH L/D OF 3½" TBG. RIH TAG TOP OF 5½" LINER @ 10246'. TAG FILL @ 10724'. MW:lO.1 TAG FILL @ 10724' AND C/O SAME TO CORRECTED PBTD @ 10854'. GEARHART RAN GR-NEUTRON-CCL LOG FROM 10832'- 8800'. SET BP @ 10550'. ATTEMPT TO TEST 5½" LINER & 7 5/8" CSG TO 2700 PSI, NO SUCCESS. MW:lO.1 TEST 7 5/8" CSG F/10155' - SURFACE WITH 2700 PSI - OK. ATTEMPT TO TEST LINER LAP - NO GOOD. BLEED OFF @ 450#/30 MIN. SQZ'D 7 5/8" X 5 1/2" LINER LAP W/19 BBL CMT SLURRY. MW:lO.1 DRILL OUT CMT RETAINER @ 10125'. TEST LINER & CSG TO 2700 PSI. LOST 80 PSI IN 30 MIN. MW:lO/1 M/U WSO TOOLS TO TEST LINER LAP. SET PKR @ 10098'. T.O.L. @ 10246'. HAD SLIGHT BLOW IN BUBBLE BUCKET HAD 210' OF FLUID RISE. CHARTS SHOWED A 50 PSI BUILD-UP OVER THE 72 MIN OPENING PERIOD. RETAINER DEBRIS BLOCKING TOP OF LINER, REC SAME W/TAPER TAP (TOL @ 10246'). RIH W/JUNK BASKET. POOH W/JUNK BASKET. BOPE. REC PIECES OF RETAINER JUNK. TEST MW:lO.1 REC RET. BP @ 10552'. R/U & RIH W/PERF GUNS TO 10732'. (BOTTOM PERF.) RAN GR F/10543'-10301'. MW:lO.1 PKR @ 10578'. RE-PERF'D: 10616'-10634'; 10664'- 10672'; 10695'-10703'; 10706'-10710'; 10726'-10732' WITH (4) ½" JSPF @ 0230 HRS. FLUID TO SURFACE @ 0541 HR (OIL & WATER). RATE: 110 B/DAY ON A 12/64 CHOKE WITH 2475 PSI TBG PRESSURE. LAST CUT TAKEN WAS 43% WATER. SHUT IN WELL @ 1019 HRS. REV CIRC OIL & WATER OUT OF D.P. KILL WELL. POOH W/PERF GUNS. 8/5/86 8~6~86 8/7/86 8/8/86 8/9/86 MW-lO.1 C/O SAND FROM 10833' TO 10854' (PBTD). RAN 13 JTS OF 2 7/8" 6.5t/ N-80 8RD TBG. RUNNING 3½" TBG. MW-6.8 RAN 3½ TBG TO 10584'. TOTAL 3½" TBG- 264 JTS OF 3½" 9.3// N-80 8RD TBG, 66 JTS OF 3½" 9.3// N-80 BUTT TBG. SHEAR SUB @ 10584'. OTIS 2 7/8" 'XN' NIPPLE @ 10458'. BAKER 7 5/8" X 3 1/2" 'FHL' PKR @ 10174'. BROWN 3½" 'CC' SAFETY JT @ 10162'. OTIS 3½" XA SLEEVE @ 10130'. OTIS 3½" 'X' NIPPLE @ 2004'. N/D BOPE & N/U TREE. CHANGE WELL OVER TO LEASE CRUDE. MW'IO.O CLEAN MUD PITS. PRESSURE TEST TBG T/2000 PSI. HAD COMMUNICATION TO ANNULUS. KILL WELL W/IO.O PPG CACL2 WATER. N/D TREE & N/U BOPE. MW'IO.O POOH W/3½" TBG. FOUND 3½" BROWN 'CC' SAFETY JT HAD BEEN PARTIALLY BACKED OUT. CHANGE OUT 'CC' SAFETY JT & 'XA' SLEEVE. RIH W/2 7/8" & 3½ TBG TO 10584'. N/D BOPE. MW:6.8 N/U TREE. DISPLACE 10.0 PPG BRINE W/LEASE CRUDE. CLEAN MUD PITS. RELEASED RIG @ 1700 HRS. Form 3160--5 {November 1983) (Formerly 9-331) i~[ "rED STATES sua,,iT m ~ (Other instruct[ DEPART . r OF THE INTERIOR ve~dde) X BUREAU OF LAND MANAGEMENT SUNDRY NOTICES AND REPORTS ON WELLS (Do not u~ this form for proposals to drill or to dt~pon or plug back to a riflE, rent r~s~rvolr. Us~ "APPLICATION FOR PERMIT--" for such prol)OmlL) ~)n ~OCATION OF WELL (Report location clearly and in accordance with any State requl~e~..ents.* St~ also space 17 below.) At surface Form approved. Budget Bureau No. 1004--0135 Expires_ August 31, 1985 5. LBABB DESIGNATION AND BI~IIAL 00. _. A-028997 !1~ INDIAN, ir,!~r~ig OR T~IBB NAME 1. Soldotna Creek Unit 2. NAME or OPE~ATOI ARCO Alaska, Inc. P.O. Box 100360, Anchorage, Alaska 99510 SCU 31-8 4. 10. fiELD AND POOl,; OB WII`DCAT Hemlock Sands 1950'FEL, Sec. 8, T7N, R9W, SB&M 1372,FEL, Sec. 8, T7N, R9W, SB&M SL: 1850t FNL, BHL: 1161' FNL, 14. PERMIT NO. 15. ELEVATIONS (Show whether DF. RT. aR, et~) 129' GL, 155' KB 11. ~B~., T., I., M, OB BLK. LIfD BUBVBY SI AIBA Sec. 8, T7N, R9W, S.M. Kenai J A~ 16. Check Appropriate Box To Indicate Nature BI Notice, Report, or Other Data NOTICE Or INTSNTION TO: TEST WATEB SHUT-OfF ~--] PULL OR ALTER CASING FRACTURE TREAT MUL~IPL~ COMPI.ETE SHOOT OR ACIDIZB ABANDON* ~EPAIR WELL CHANGE PLANS (Other) SUBIBQUBNT IBI~I~ OF: fRACTURE TumATMElqT . ALTEBING CASINO . 8HOOTING OB ACIDIZING ABANDONMENT0 (Other) (NoTs: Report results of maltiple completion on Well' Completion or Reeompletion Report and Log form.) 17. UgS('RLq~; PnOPOSEO OB COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any propo~d work. If well is directionall¥ drilled, give subsurface locations and measured and true vertical depths for all markers and ~ones p~rti- nent to this work.) $ A Workover on Well SCU 31-8 was performed to repair Tubing/Production Casing communication and return this well to production. The details of this workover were as follows: 1) Accepted Rig (Brinkerhoff #16) @ 1800 hrs on 7/24/86 to begin workover. 2) ND production tree, NU BOPE. POOH with all tubing and the production packer. 9) 10) ll) 3) Ran Gearhart GR/Neutron/CCL log from 10,832' to 8,800' MD. 4) Set retrievable bridge plug at 10,155' and pressure tested (PT) casing to 2700 psi. 5) Squeezed 5" liner lap with 100 sacks of Class "G" cement. 6) Set retrievable bridge plug at 10,246' and PT 5" liner to 2700 psi. 7) Reperforate with Baker 3-3/8" tubing conveyed guns, 4 SPF: 10,616 - 634; 10,664 - 672; 10,695 - 703; 10,706 - 710; 10,726 - 732. 8) RIH with completion assembly as follows: 13 Jts. of 2-7/8", 6.5#, N80, 8rd Tubing; 264 Jts. of 3-1/2", 9.3#, N80, 8rd Tubing; 66 Jts. of 3-1/2", 9.3#, N80, Butt Tubing; w/ a Baker shear out sub @ 10,584, an Otis "XN" nipple @ 10,174, a Baker "FHL" packer at 10,174, a Bro~ Safety Jt. @ 10,162, an Otis "XN" sleeve @ 10,130 and an Otis nipple @ 2004. ND BOPE, NU 5000# production tree. Release Rig @ 1700 hrs on 8/9/86. Well returned to production at 102 BOPD/ 4 BWPD/ 29,000 SCF/STB on $/15/86~ 18. I hereby certtf~ that the fore. going ts ~J~ae and correct TITLE Regi.ona! Engineer (This space for Federal or State office use) APPROVED BY CONDITIONS OF APPROVAL, LP AN~: TITLE DATE *See Instructions on Rev.n,, Side Title 18 U.S.C. Section 1001, makes it a crime for any person knowingly and willfully to make to any department or agency of the United States any false, fictitious or fraudulent statements or representations as to any matter within its jurisdiction. TRANSMITTAL AND ACKNOWLEDGEMENT OF RECEIPT OF CLASSIFIED MATERIALS Alaska Oil & Gas Conservation Commission Attn: Mr. W.M. Van Alen 3001 Porcupine Dr. Anchorage, AK 99501-3192 WELL NAME' ~C~] J) "' ~ We are sending the material tabulated below. Please acknowledge receipt and return one copy to: Mr. j. L. Weaver Chevron U.S.A. Inc. 3001 C Street Anchorage, AK 99503 RECIPIENT PLEASE ACKNOWLEDGE COMPANY' BY' DATE: · · Devel op~mer~ Geologist Senders~ Instructions:- These transmittal sheets are made on NCR (No Carbon Requi~ed} paper with three sheets per set. Retain one copy for originator's file. Include one copy with transmitted material. Send original under sepa- rate cover to addressee. (If sending by air freight, put air bill number on backside of envelope.) Please use ball-point pen when filling Out this form. EXP-180-8 (C0-3-82) Printed in U.S.A. APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing E~ Amend order [] Perforate ~ Other 5. Datum elevation (DF or KB) G.L. = 129' K.B.= 155 6. Unit or Property name Soldotna Creek Unit 7. Well number SCU 31-8 2. Name of Operator Chevron U.S.A., Inc. 3. Address P.O. Box 107839, Anchorage, AK 99510 4. Location ofwellatsurfacelg02, S & 1968' W of NE Corner Section 8, TTN, R9W, SB&M Attopofproductiveinterval 1269' S & 1968 Section 8, T7N Ateffectivedepth 1218' S & 1313' W of Section 8, T7N, R9W, Attotaldepth 1213' S & 1308' W of Section 8, T7N, R9W, ' W of NE Corner , R9W, SB&M NE Corner SB&M NE Corner SB&M 8. Permitnumber 81-0099 9, APInumber 50-- 133-20344 10. Pool Hemlock 11. Present well condition summary Total depth: measured true vertical 10,904 10,783 feet feet Plugs (measured) 10,904' - 10,860' Effective depth: measured true vertical 10,860 10,740 Casing Length Size Structural Conductor 40 ' 20" Surface 3,353 ' 10-3/4 Intermediate 10,424 7-5/8" Production Liner 656' 5-1/2" Perforation depth: measured 10,616 - 10,634' 10,6 ~r4ue-ve]r~da617 2 ' 10,501' - 10,519' 1 ' 10, .548' . -meb0sbSr~ depth) Tubing (size, grade an(3 feet feet 10,695' 10,706' Junk (measured) Cemented Measured depth 72' 3,383' 10,452' 10,578' 10,589' 3-1/2" 9.30# N-80 8RD EUE at 10,416' Packers and SSSV (type and measured depth) Baker 7-5/8" "V~qT." Pmr~v @ !0.203' 12.Attachments Description summary of proposal [] - 10,703' - 10,710' - 10,586' - 10,593' 10,902' 10,726' 10,608' 10,732' 13. Estimated date for commencing operation 14. If proposal was verbally approved - 10,614' · ,.P F('F l\/Pn Detailed operations'program E~ ~0~' sketch ~v True Vertical depth 72' 3,383' 10,341' June 15, 1986 10,781' ~ln.~ka Oil & Gas Con.~. Commission Anchorage Name of approver Date approved 15. I hereby j~ertif~y that the foregoing is true and correct to the best of my knowledge Signed ~._~~ TitleArea Operations Superintendent Date Conditions ol approval Commission Use Only Notify commission so representative may witness I Approval No. [] Plug integrity ~ BOP Test [] Location clearance I Commissioner Approved by Form 10-403 Rev 12-1-85 - by order o ~ ~, ~'~ I/' the commission Oate~"-:~-'~:~ Submit in triplicate PRO PROPOSAL FOR WELL OPERATIONS Well: Field: Location: Elevation: Present Status: SCU 31-8 Swanson River At surface: 1902' S & 1968' W of NE Corner Section 8, T7N, R9W, SB&M At Total Depth: 1213' S & 1308' W of NE Corner Section 8, TTN, Rgw, SB&M G.L.= 129' K.B.= 155' TO 10,90U' (MD); 1o,783, (TV[:)) PBTD 10,860' (MD); 10,7~0 (TVD) Casing: 20"@ 72' 10-3/W' cemented @ 3383' 7-5/8" cemented @ 10,~52' 5-1/2" 20tt N-80 Liner: 10,2~6' - 10,902' BHT: 172° F Perforations: 10,616' - 10,63~' 10,66~' - 10,672' 10,695' - 10,703' 10,706' - 10,710' 10,726' - 10,732' NOTE: In 3anuary 1986, the pressure on the 7- 5/8" casing annulus was 3600 PSI and would not bleed down below 2100 PSI indicating tubing/casing communication, a packer leak or a casing leak. BLOWOUT CONSIDERATIONS; . . . ® Gas_._: This well has produced over 3000 MCF/D. Care must be taken at all times not to swab the well and to keep the hole full on trips. Lost Circulation: None anticipated, but lost circulation material (salt pills) should be readily available at all times. Precautions: Any kicks should be handled by normal procedures. Rig crews should be made aware of these methods, and care must be exercised at all times. Maximum Anticipated Formation Pressure: §250 PSI from build up 7-1)5. Programmed mud weight of 9.I) PPG will provide 190 PSI of overbalance. Maximum Anticipated Surface Pressure: 3600 PSI from integrity test 1-86. Blowout Prevention Equipment: Minimum of Class III - 5000 PSI. RECEIVED MAY 2 7 1986 Alaska Oil & Gas Cons. ~;u,,~.~s~on Anchorage SCU 31-8 WORKOVER PROGRAM ® . . . 10. 11. 12. 13. Notify Swanson River Production to pull dummy valve from gas lift mandrel at 10,160' and to make sure that there are dummy valves in all other gas lift mandrels. Install back pressure valve. Move in and rig up workover rig. Remove BPV and kill the well using workover kill program). fluid (see attached Install BPV, and nipple down the production tree. Nipple up the Class III 5,000 PSI BOPE (see attached drawing). Test BOPE to 5000 PSI (annular to 3500 PSI). Notify the BLM and AOGCC 2~ hours in advance to witness the test. Remove the back pressure valve. Pull out of the hole, and lay down the 3-1/2" tubing and associated production equipment (see attached detail). Pick up and trip in hole with a t~-5/8" bit, 5-1/2" 20# casing scraper, and sufficient 3-1/8" drill collars and 2-7/8" drill pipe and 3-1/2" drill pipe to clean out to 10,860' (PBTD). Circulate the well clean. Pull out of the hole. Run a GR/Dual-space Neutron/CCL log as directed by Anchorage Engineer- ing. Trip in hole with 5-I/2" retrievable bridge plug and 7-5/8" retrievable packer. Set RBP at +/- 10,550' and the packer above the 5-1/2" liner top and test liner/liner lap to 2700 PSI. Test the 7-5/8" casing above the ret. packer to 2700 PSI. Locate leaks ii there are any. A squeeze procedure will follow ii needed. After all squeezes and clean out runs are made, make a 7-5/$" casing scraper run to top of liner, and a 5-1/2" scraper run ii necessary. NOTE: IF IT IS DECIDED NOT TO PERFORATE, GO TO STEP NO. 18. Trip in hole with tubing conveyed perforating guns on drill pipe. Service company and type of guns will be determined later. Space out perforating guns using a GR log. Nipple up test head, surface lines, and test manifold. Test to 5000 PSI. Reperforate selected intervals as directed by Production Engi~l~r[~v~i~~-r~:~ (6) 3HPF and a I000 PSI underbalanced nitrogen cushion. i~~---- MAY 2 7 1986 Alaska Oil & Gas Cons, com~SSiO~ Anchorage 22. 23. 15. Flow the well on an 8/64" choke, and production test well per Anchorage Engineering. 16. Open packer by-pass and reverse the well dead. 17. Release the packer and circulate the well. Pull out of hole with the perforating guns. 15. Trip in hole with 4-5/$" bit, casing scraper~ and drill string. Circulate the well clean. Lay down the drill string. 19. Run the 3-1/2" production string per the attached tubing detail. Internally test the tubing below the table to 5000 PSI. Space out and land the tubing with a full joint on the top. 20. Install the back pressure valve. Nipple down the BOPE and nipple up the production tree. Test to 5000 PSI. 21. Displace brine water down the annulus with lease crude until clean crude returns are obtained at the surface. Set the production packer and test the packer/annulus to ]500 PSI for 30 minutes. Install the B.P.V. Release the rig and return well to production per the Area Production Foreman. D. R. Meier RECEIVED MAY 2 ? 1986 Naska 0il & Gas Cons. Commission Anchorage WORKOVER FLUIDS PROGRAM SCU 31-8 SWANSON RIVER FIELD FLUIDS SYSTEM: PROPERTIES KILL CIRCULATING Type Litesal/Liteplug Litesal/Liteplug Weight(PPG) 10.2 9.8 Viscosity (SEC/QT) 65- 70 35- 50 Fluid Loss (CC/30 Min) 5 - ? NC Plastic Vis. (CPS) 8- 10 8- 10 Yield Pt. (Lbs/100 Ft2) 20 - 30 8 - 12 Gels (Lbs/100 Ft2) 8/12 3/3 pH 9 8 Solids (96 by Volume) 17 7 Use primarily a brine water system with the above pills for either kill plug setting or viscous sweeps. If cement squeezes are required, pretreat for cement contamination prior to drilling cement. MAY 2 7 1986 Alaska Oil & Gas Cons. commission Anchorage -1513.55~ 3753. ~92. 4500.64'~' 4503'00' S302. y5,_L~ 5343 66'. 5815. 5~[9. fi097. 6105. 6107. 6508. 6517. 6519. ~"0,160.48'-- 92' 83'--~ 43'- 80' -- KB correction 1-jr 3~ 9.3i~ 8rd N-80 TBG '- 1-Otis 5 ni~Dle. Dos. 4, 2. 875 ID 47-jts ~ 9:]~/ 8r~ N-80 TBG *'L-Gas ~;=~_~.,.~. 'r-gndrel 1-Pt~ 25. ' 31.65~ 1.16' 1477.13 8.61' 2.42' 40 j ts ~'~ 9.3~i: 8rd ~,-" 80 TBG 1236.63 ~=' :.~ndre . ' *1 Gas 1~ 1 8 65 1-~-%,m 2.32' 32-i~s 3~.~ 9 ~:~ 8rd .ti-80 TSG 978 89' *l-Gas lift 1-?v? 2.35' 24-jts 3P 9.3// 8rd ~I-80 "'I-G,~ lift ~ ',mndrcl 1-Pup 26-jks 3~ 9.3f~ 8rd ~-80 '123 *1 Gas lift N~.ndrel 1-P~ 16-.i~ 3'~ 9.3# 8rd ~-80 TBG *I-C.'~s lift .'.nndrel 9-j t.~ 3'~ 9.3;~:,~ 8rd :'~-80 ~G ¢'l-Oas l~t ~',~ndrel L-Ik~ ll.3-j~' "" ':. 3v" 3rd -~.:30 ~G 738.55' 8.64' 2.36' 799.75 8.59 2.32 494.57 8.65 2.30 277.96 8.57 2.21 400.91 8.6C 2..37 3640.6~ 10 ,169 .14, _1~ "'l-Gas lift ":'.:::.ti 8.66 10,171 37' I ' 1-?ur~ 2.23 ,_j 1-jr :.! .'".2.':~ ]ri ::-$0 T.g.,?_, 31.23 10, 202. 60,_~. 1-7 5/8~;,:::'.:::- :~F~ ?:::.:er 10,209 50, ,~ · 1-Otis ~o~Lti::: £ S :[i:~!e 1167 s~o · 10 211 92' - L-X-0 8rd 3:: :: ~.::L L:;.: ~L~ .75 ' ~, ;[-80 203.37 10 415 29 7-j~s 3~.~ },J./ ,',,:T,::o ~,3~L ~ '- ' ~ v n e¢~ -,'. ,~.. ,.. = .... ~Ln .85 ' 1-3~/' Baker ::'.,~'- q,'h .78 lmndcd ~'~ 4 ~o ~a ~ R C IV D pipe ~ holt 10,391.92 " ' S C U 31 8 A~chorage 0 A S I N G & T U B i N G O ET A I L SECTION 8 T. 7 N~RgW. ELEV. 1~8' 6.L. *All gas. lift mandrels are Md:'L~ry-tfu~hes, ._ -~ 1 jo" ,~ ~r~ ,.H,h 1 117" ~d~ ~l~.~. ~ P~'RFDRA TE U#DERBALAAICE AS DIREC. TEl9, OLO ' t:~ERFORATIOAI$ MAYBE OPEN /lAID Il' Pt',~Y A/OT _ 8~ POSSIBLE TO ACHIEVE UAZDERBAL~A/CE. .... ~ Z ~a" ~ $ ~/~" I'2RIL L ?/PE T~ SURFA CE · PRE, SSUR~ ACTIVATED PUMP OI.(T $U8 ' IJT Z~/a" ~.7# AI-~O ~RO EU~ 'F/~O · / dT ~,'#"~.7~ AJ-80 ~1-¢0 EUE - 'RETRI£VASLE --" I JT 2 ~" ~. 7~' AI-80 ~/-CD EUE TBG · .SLIDING ,SLEEVE - .SPACE AS REQUIRED · BAR DROP F/R/A/~ /-/EAO --- -$3/a" TC? GUNS (~-72" u'/IP? (DEPTI-I CRITICAL AS DIRECTED) RECEIVED MAY 2 7 1BBG Alaska Oil & G;~s (;o~s, 6o~missiom ,CHEVROA/ USA IAIC .. 3'/z'"X"N/PPLE ~ ~ 500' GAS LIFT MANDREL5 AT THE DEPTHS' 65/2.; 6/0/,~ 5'8/2 37V6~ ' 2,. 757;. FOLLOIVlNCa 5507,' '-/"/96; 5'/,z" ~.3 '"*/v-so £AfCC~O "/¥,~" NAA/ORE/_ ~ 10165 / jT' $'~. 9.~ ,: '--'.TS/e"x3~6'''' "FH" PACKER ~ 102.05' -- 2'Ve X Svz X -OV~;/~ ~O EUE 7'FJ~ elm -- /0 ,TT5 ?.~" 6.5' N-gO 8RD [UP. Tg~S. ---- P..~S" '%¥" TFJG ?,~ 7',0--/o, 860' RECEIVED MAY 2 7 1986 AJaska 0ii & Gas Cons. Commissior~ $CU 31-8 ~WA~DAI 3EC. ~ . TTN~ CHEVNO// DETA IL. UN/7'. 1A/C,.. CHEVRON U.S.A. TRANSMXTT~.? 3 ACKNOWLEDGEMENT OF RECEIPT(' INC. tATmU:AL - (ALAS~) ~.P~.: ,~.O.(m. C.C. DATE THE FOLLOWING IS A LIST OF MATERIAL ENCLOSED HEREIN. Fl)- Folded R - Rolled S - Sepia F - Film X - Xerox B - Blueline PLEASE CHE6/( AND ADVISE IMMEDIATELY. JEA. 3 q-q RECEIVED 8Y Chevron DATE THE FOLLOWING IS A LIST OF MATERIAL ENCLOSED HEREIN. -- FD-- Folded R - Rolled S - Sepia F - Film X - Xerox B - Blueltne PLEASE CHECK AND ADVISE IMMEDIATELY. 'L /! Ual ¢- 3~ ', II I ' ii ii i -- m . RECEIVED - ~i~~N U.S& BOX 7.,,839 REMARKS ON OTHER SIDE, THIS sHE'ET 'ANO.~ORAGE, ALASKA 99510 4Bf£' ~ 56.65.~J,... .' 57'8ti~_' .... .. 1504.94 ~ .1513.55,_/ 1515.97;' ~ 2752.60'2 . 2763.57' I L -- 3742.46'-J 3751.10,_>: ; . 3753.45' -- ,' .... ._4492. O0 .- __4500.64'->' s°3.oo L 5302. 5311.34'--F 5343.66' 5816.88'--dz 6097 14'~ n'- 6107.92' 6508. 83'-- ~ 6517.43'-- 6519.80( -- i:'o, z o. 48'- zo, ,, 10,171.37' 10,202.60 10, 211.17'~ ~o,4~5.29'-~ 10,416. ~4~~ -.) *Ail gas lift mandrels are Md,hrry-thghes, -3 1/2"i.'Srd ~ with 1 1/2" side pockets. KB correction 1-jt ~ 9.3# 8rd N-80 TBG - 1-Otis 5 nipple, pos.4. 2.875 iD .. 47-jts 33~ 9]]# 8rh N-80 TBG *'i-Gas lift },~ndrel 1-Pup 40 j~s 3~ 9.3# 8rd N-.8.0.TBG_ *1 Gas lift 1.Enndrel 1-Pup 32-jEs 33~ 9.3# 8rd N-80 TBG *l-Gas lift l,~ndrel *l-Gas 24-jts 3~ 9.3# 8rd N-80 TBG lift HandreI 1-Pu~ 26-j~s 33~ 9.3# 8rd N-80 TBG *1 Gas lift b~ndrel 1-Pup 16-jts 3~ '9.3# 8rd N-80 TBG *l-G~s lift Mandrel 9-j ts 3>~ 9.3# 8rd. N-80 TBG *l-Gas lift Mandrel 13 jts 3~' 9.3" 8rd N-80 TBG *l-Gas bbndrel 1-Pup 31.65' 1.16' landed @ 10,416.92 i.. ~£pe in hole 10,391.92 1477.13' 8.61' 2.42' 8.65' 2.32' 978.89' 8.64' 2.35' 738.55' 8.64' i_2.36' 799.75' 8.59' 2.32' 494.57' 8.65' "'2',"30' 277.96' 8.57' 2.21' 400.91' 8.60' 2.37fi 3640.68' 8.66'! 12.23': S. C.U. 31-8 CAS lNG 8, TUBING DETAIL SECTION 8 T. 7 N:,RgW, ELEV. 128' G.L. - II I I I II ll8-jts 3~ 9.3# 8rd ].-80 TBG *l-Gas lift 1,kndrel 1-Pup 1-jr 3~ 9,3# 8rd N-80 TBG 31.23' 1-7 5/8 Baker FEL' Packer .................. -6 :' 90' 'l-Otis Position 2 S Nipple 1.67' l-X-0 8rd BX X Seal Lok Pin . . 75' 7-jts 3;5 9.3# Armco Seal Lok N-80 203'~37' 1-X-O Seal Lok Box X Butt. Pin .85' 1-3~" Baker Shear Sub .78' A(~, STATE OF ALASKA (~ ALASK f'L AND GAS CONSERVATION C ,,~MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER I"1 2. Name of Operator 7. Permit No. Chevron U.S.A. Inc. 81-99 3. Address 8. APl Number P. O. Box 107839, Anchorage, AK 99510 50-133_20344 4. Location of Well 1850' S & 1950' W of the N.E. Cor., Sec. 8, T7N, R9W, S.M. 5. Elevation in feet (indicate KB, DF, etc.) 128' G.L. I 6. Lease Designation and Serial No. A-028997 12. 9. Unit or Lease Name Soldotna Creek Unit 10. Well Number SCU 31-8 11. Field and Pool Swanson River - Hemlock Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] ~, Perforations [~ Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] r Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). On May 10, 1983, the following procedure was performed on SCU 31-8: 1) Shut in well. Tested lubricator to 4000 psi. 2) Perforated the H,8 and H-9 intervals 10,616' - 10,634' 10,664' - 10,672' 10,695' - 10,703'f 10,'706' - 10,710' w±th 4 GHPF and 0© phas±ng. 3) Returned well to production from all zones., t~.that the foregoin is true and correct to the best of my knowledge. 14. I hereby cer O~, ~ Signed · Title J ECEIVED MAY 2 ? i983 The space below for Commission use Area Engineer Date Conditions of Approval, if any: Approved by By Order of COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate K(~ STATE OF ALASKA " ' ALAS OIL AND GAS CONSERVATION [O,v, MISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL COMPLETED WELL [] OTHER r'] 2. Name of Operator 7. Permit No. Chevron USA Inc. - 81-99 3. Address 8. APl Number P. O. Box 7-839, Anch., Ak 99510 50-133-20344 4. Location of Well 1850' S & 1950'W of the NE Cor., Sec. 8,T~,RgW, .S.M. 5. Elevation in feet (indicate KB, DF, etc.) ]28'G_L. 12. I 6 . Lease Designation and Serial No. A-D2RC)q7 9. Unit or Lease Name Soldotna Creek 10. Well Number SCU 31-g 11. Fie, Id and Pool Swanson RiverLHemlock Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate ~ Alter Casing r-I Perforations [] Altering Casing [] Stimulate [] Abandon I-] Stimulation [] Abandonment l'-I Repair Well· [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other ]~ Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 A'Ac 25.105-170). It is proposed to test and complete well SCU 31-8 as follows: (Work to conmence upon receipt of approval) . 1. Perforate and test H-10 sand from 10,726'-10,733'. 2. If the H-10 sand is unproductive - isolate with a thru-tubing bridge plug. If the H-10 is productive (low GOR and water cut) - retain. 3. Perforate and test H-9 sand from 10,695'-t0,703'. 4. If the H-9. sand is unproductive - isolate with thru-tubing bridge plug. If the H-9 is productive-- retain. Perforate and test lower H-8 sand from 10,664'-10,672'. If the lower H-8 sand is unproductive - isolate with a thru-tubing bridge plug. If the lower H-8 is productive - retain. 7. Perforate and test the.upper H-8 sand from 10,616'-10,634'. .~la~ka 0l! & Gas Cons. Comtnl~io~ Anchorage - ., 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. -\ '' Area ~lgneo., I :,.f ' ~"~ Title ~,~,eer The space below for CommissiOn]use Date 9/16/82 Conditions'of Approval, if any: Approved by COMMISSIONER Form 10403 Rev. 7-1-80 By Order of the Commission Date, Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ALASKA ,L AND GAS CONSERVATION C ,,MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER [] 2. Name of Operator 7. Permit No. Chevron U.S.A. Inc. 81-99 3. Address 8. APl Number P. O. Box 107839, Anchorage, Alaska 99510 50-133-20344 4. Location of Well 1850' S & 1950' W of the NE Cor., Sec 8, T7N, R9W, S. B&M 5. Elevation in feet (indicate KB, DF, etc.) 128 ' GL 6. Lease Designation and Serial No. A-028997 9, Unit or Lease Name Soldotna Creek Unit 10. Well Number SCU 31-8 11. Field and Pool Swanson River - Hemlock 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate ~ Alter Casing [] ~ Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Refer to Sundry Notice dated 9-16-82. Please amend that report to include the perforating of the lower H9 interval 10706 - This interval along with 'the intervals proposed on the 9-16-8.2, notice will be shot "~: at the same time. We plan on doing this work during the week of May 2, 1983. Signed14' I hereby certify~]). ~that the fore~rect to the beStTitle Area Engineer°f my knowledge. The space below for Commission use Date Conditions of Approval, if any: ORIG~,~L SIGNED B! LOI, iNI£ I~. SltlITil Approved by_ COMMISSIONER Approved Copy ,~turned By Order of the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate COMPLETION REPORT - NEW WELL AREA: Soldotna Creek Unit LAND OFFICE: Anchorage, Alaska PROPERTY: SwaIlsorl River Field' LEASE NO: A-028997 WELL NO: SCU 31-8 API NO: LOCATION AT SURFACE: -~~~ W of the N.E. Cor., Sec. 8, TTN, Rgw, S.H. · LOCATION AT TOTAL DEPTH: 689' N & 578' E of Surface ELEVATION: 128' G.L. DATE: 1/83 DATE COMPLETED RETURNED TO PRODUCTION: DRILLED BY: Brinkerhoff Signa~ Inc. Rig #54 DATE COMMENCED .' WORK: 6/20/82 WORK: 10/7/82 10/19/82 TOTAL DEPTH: 10,783' M.D. EFFECTIVE DEPTH: 10,860' I'~.D. (cmt.) CASING: 20" at 72' 10 3/4" at 3383' 7 5/8" at 10,452' 5 1/2" at 10,246'-10,902' SUMMARY PERFORATIONS: 10,726' -10,732' RECEIVED JAN2 11983 Alaska 0il & Qas Cons, Commissi'o. Anchorage 6/20 - 6/25/82 Moved in and rigged up Brinkerhoff Signal Inc. Rig #54. 6/26 - 6/27/82 9.2 ppg Drove 20", 94# H-40 casing to 72'. Cut off 20" casing and nippled up 20" BOPE. Spudded well at 8:00 am 6/26/82. Drilled 14 3/4" hole 72'-1100'. 6/28/82 Drilled and surveyed 14 3/4" hole 1100'-2125'. 9.3 pgg 6/29/82 Drilled and surveyed 14 3/4" hole 2125'-3390'. hole for logs. 9.6 ppg Circulated and conditioned 6/30/82 Ran DIL/GR fr~a 3375'-surface. 9.8 ppg 7/1/82 Circulated large amounts of coal m~d clay. Ran 10 3/4" casing as follows to 3383', float collar at 3304': 10 3/4" Baker 40.5 # Butt. Shoe 2 jts 10 3/4" 40.5# K-55 Butt 10 3/4" Baker Stab in Float Collar 85 jts 10 3/4" 40.5# K-55 Butt. Landed at - Casing cutt off Casing in well 1.15' 76.80' 1.80' 3303.74' 3383.49' 29.50' 3353.99' Mixed and pumped 149© sx Class "G" cemmnt. Slurry wt. = 13.2 ppg, yield = 1.86 c. f/sx. Circulated 190 sx. to reserve pit. Had full returns throughout cenmnt job. Displaced with 5 bbls water and 53 bbls mud. '7/2/82 Waited on cement. Nippled up Class III BOPE. 7/3/82 8.8 ppg Tested rams and choker manifold to 500 psi - Hydril to 2500 psi. Drilled cenmmt 3213'-3383'. Mistakenly drilled out of shoe. Casing test would not hold. RECEIVED JA N2 11 t83 Anchorage 8.8 ppg 7/4/82 Drilled and s~rveyed 9 7/8" hole 3391'-3927'. 7/5/82 8.8 ppg Drilled 9 7/8" hole 3927-4084'. Set MITS Howco Packer at 3368' and tested casing to 2500 psi - 30min. - o.k. Layed down packer. Drilled 4084'-4264'. 7/6/82 - 8/1/82 9.1 ppg 12.0 ppg Lost cone 12.0 ppg 12.1 ppg 12.1 ppg 10.0 ppg 12.0 ppg 12.0 ppg 12.0 ppg 12.0 ppg 11.9 ppg Ran DIL-BHC-SONIC-SP, CNL 10,533' -3385' . RECE IVED Drilled 9 7/8" hole 4264'-9685'. Bit started torqueing. off 9 7/8" bit. 8/2/82 Fished for cone. 8/3/82 Fished for and milled on lost cone. 8/4~82 Fished for co~. Recovered 90%of fish. 8/5/82 Drilled 9 7/8" hole 9794'-9955'. 8/6/82 Drilled 9955'-10,037'. 8/7/82 Drilled 10,037'-10,190'. 8/8/82 Drilled 9 7/8" hole 10,190'-10,320'. 8/9/82 Drilled 10,320'-10,521'. 8/10/82 Drilled 10,531'-10,535'. JAN2 119B3 Al~s~ Oil & Gas Cons. Commission Anchorage 8/11/82 11.9 ppg Ran 13 sidewall sample guns with full or partial recovery in 12 shots at the following depths: 10,517, 10,514, 10,510, 10,505, 10,501, 10,497, 10,492, 10,488, 10,438, 10,473 (no recovery), 10,448, 10,382, 10,378'. Circulated and conditioned hole for 7 5/8" casing. 8/12/82 11.9 ppg Ran 7 5/8" casing to 10,452'-float collar at 10,367' and Baker cement stage collar at 7459' as follows: Length KB to Braden Hd 3 jts 7 5/8" 33.7# 595 8rd LT&C 1 xo LT&C Box X Butt Pin 69 jts 7 5/8" 26.4~ N80 Butt 49 jts 7 5/8" 26.4~ 595 Butt 1 xo Butt Box X LT&C Pin 61 jts 7 5/8" 29.7# 595 LT&C 8rd 1 Baker ~del J Stage Collar 18 jts 7 5/8" 29.7# 595 LT&C 8rd 51 jts 7 5/8" 33.7# 595 LT&C 8rd 1 Baker Float Collar Differential Fill 2 jts 7 5/8" 33.7# 595 LT&C 8rd 1 Baker Float Shoe Differential Fill 25.00' 94.49' 1.13' 2,906.35' 1,869.40' 1.15' 2,562.17' 1.58' 761.94' 2,139.79' 1.75' 84.75' 2.50' 10,452.00' 8/13/82 11.8 ppg Rigged up Dowell F02 two stage cement job. 1st stage: pumped 20 bbls. Caustic flush (5#/bbl caustic). Mixed and pumped 800 5% Class "G" cmt. (15.8#/gal) (1.15 C.F/SX) (4.97 gal/sx./water). Dropped wiper plug. Displaced with drilling mud. Canmnt set up while displacing. Estimated top of cement at 8745'. Dropped stage collar trip plug to open D.V. tool at 7463'. Unable to open D.V. collar. Attempted to seat plug in D.V. collar with wireline sinker bars. W.L. tool stuck in hole. 8/14/82 Unable. to free W.L. tools - d~opped McKinley cutter to cut wire at top of tools. Cutter did not work. W.L. parted at surface. Picked up W.L. spear and ran in hole with drill pipe to fish for W.L. recovered +700' of W.L. - 8/15/82 11.4 ppg Recovered all of wireline and wireline tools fish. Attempted to seat D.V. ~plug in D.V. collar by spudding on plug with D.P. RECEIVED JAN2 11983 Alaska Oit & Gas Cons. Commission Anchorage 8/16/82 11.4 ppg Abandoned 2nd stage of 7 5/8" csg. cement job. Set slips on casing and nippled up tubing head. 8/17/82 11.5 ppg Nippled through in hole up BOPE's. Ran in hole with bit and drill collars. Drilled D.V. collar and pressure tested D.V. collar to 2000 psi. Ran to 8394 '-tagged cement at 8394'- and drilled cement to 8510'. 8/18/82 11.6 ppg Drilled cenmnt 8510'-9138'. 8/19/82 11.5 ppg Drilled cement 9138'-~9141'. 8/20/82 11.4 ppg Drilled cement 9841'-10,434'. 8/21/82 10.3 ppg Made 7 5/8" casing scraper run. P~n CBL-10,415'-8,500' (good cement bond 10,415'-10,010'). Tested 7 5/8" casing to 3000 psi - o.k. 8/22/82 9.7 ppg Drilled cenmnt 10,434'-10,449' Drilled 7 5/8" casing shoe 10,449'-10,452' and washed to 10,535'. Drille~ and surveyed 10,535'-10,715'. 8/23/82 Drilled 6 5/8" hole 10,715'-10,904' 9.7 ppg 8/24/82 9.7 ppg Ran DIL/SP/GR w/BHC/ACCOUSTILOG/C~/SP/~, CDL/CNL/GR 10,902' -10,452'. Shot and recovered 15 sidewall samples. 8/25/82 9.7 ppg Ran 16 joints (652.63') 5 1/2", 20#, N-80 Butt. Liner 10,902'-10,246'. Cemented liner as follows: 20 bbl. caustic pre-flush (10#/bbl), 5 bbl water, 86 sx densified (16.3 ppg) Class "G" cenmnt containing 5% KC1, 1.2% D-19, 0.05% D-31, 0.2% D-6, 0.2% R-5. Dropped plug, displaced 'cement with 2 bbl water followed by 81 bbl mud. Did not bump plug-float held o.k. Reversed out. No cement returns. Tagged top of liner. No cement. Circulated with no cement returns. JAN2 1 Gas Cons, Commission Anchorage ~8/26/82 9.6 ppg Tagged cenmnt 10,704'-cleaned out cement to 10,746'. Pressure tested 5 1/2" liner lap to 3000 psi - Bled back to 2225 psi in 30 min. 8/27/8_____~2 9.6 ppg Drill cement and rubber plug 10,746'-10,856' Circulated bottoms up. Run in hole W/open ended 2 7/8" to 10,259' (i0' inside 5 1/2" liner) .Pumped 2 bbl. water, 3 bbls. caustic pre-flush (10#/bbl), 2 bbl water and 19 sx densified (16.3 ppg) Class "G" cement with 5% KC1, 1.2% D-19, 0.5% D-31, 0.2% D-6 and 0.2% R-5. Displaced with 2 bbl. water followed by 64 1/2 bbl. water. 8/28/82 9.7 ppg Closed pipe rams and squeezed with 3 bbls mud. Downsqueezed 7 5/8" x 10 3/4" annulus with 2 bbl. water,· 13 bbl. caustic pre-flush (10#/bbl), 850 sx (1488 C,F. ) Class"G" cement with 2 1/2% gelled water, 3 bbls water. Waited on cement. Bled pressure off drill pipe. Could not locate cenmnt on top of liner. Tested 5 1/2" liner lap to 3000 psi. Bled off to 2800 psi in 30 min. Ran in hole to 10,856'. No cement inside liner. Tested liner through drill pipe to 3000 psi - pressure dropped 100 psi/l/2 hr. (1 1/2 hour). 8/29/82 9.7 ppg Pressure tested through kill line - bled off 150 psi/30 min. (1 hour). Ran in hole with Baker Packer to 10,170'. Pressure tested through manifold to 3000 psi - bled off 50 psi/5 min. (300 psi/30 min). Repressured to 3000 psi - bled off 150 psi/30 min. Pressure tested annulus through kill line to 3225 psi. Held for 1/2 hr. ok. Ran in hole with 2 7/8" open ended 2 7/8" drill pipe to 10,263' and pumped 2 bbl water, 3 bbl caustic pre-flush (10#/sx), 2 bbl. water, 35 sx densified (16.3 ppg) Class "G" cemmnt with 5% KC1, 1.2% D-19, 0.5% D-31, 0.2% D-6 and 0.2% R-5. Displaced with 4 bbl. water and 61 1/2 bbl. mud. Had 1 bbl. cmt returns. Closed pipe rams and squeezed 4 bbl. mud. 8/30/82 9.7 ppg Waited on cement. Bled pressure off drill pipe. Unable to locate cement on top of 5 1/2" liner. Pressure tested liner lap to 3000 psi - bled off to 2650 psi in 30 min. Repressure tested liner lap with the same results. Run in hole with open ended 2 7/8" drill pipe to 10,259' and pumped 5 bbl water, 3 bbl caustic pre-flush, 2 bbl water, 100 sx (20 1/2 bbl) Class "G" cement with 0.5% D-31, 4 bbl water, 59 1/2 bbl mud. Had 1/2 bbl cenmnt returns. Hesitate squeezed 6 1/2 bbl. mud. RECEIVED JAN2 1 191 3 Aias~ Oil & Gas Cons~ Commission Anchorage 8/31/82 9.7 ppg Waited on cenmnt. Bled off pressure on drill pipe. Tagged cement at 9975'. Cleaned out cemmnt 9975'-10,264' (top of liner). Pressure tested liner lap to 3000 psi seven timms. Bled off to 2425 psi in 30 min. 9/1/82 9.8 ppg Drilled out cen~nt 10,246'-10,260' (fire cement), 10,260'-10,320' (stringers). Ran in hole to 10,856' and circulated. Set Baker Retrievamatic Packer at 10,256'. Tested liner lap to 3000 psi - o.k. Tested annulus and liner lap - bled off 500 psi in 4 min. Ran in the hole to 10,260'. 9/2/82 9.8 ppg Pumped 30 sx Class "G" with .5% D-31 and .2% D-6. Displaced with 62 bbl mud and 5 bbl water (130' balanced plug on liner lap).. Reversed out 2 bbl contaminated mud. Squeezed liner lap without success. Waited on cenmnt 23 hours. 9/3/82 9.8 ppg Drilled out cen~nt 10,221-10,246 (very soft). Tested liner lap to 3000 psi - ok. Drilled firm cenmnt 10,254'-10,270'. Run in hole to 10,856' Circulated. Tested liner lap to 3000 psi - o.k. Ran CBL-VDL from 10,866'-10,200' (10,866'-10,470-100% bond, 10,470'-10,260' - very poor bond, 10,260'-10,200'-100% bond). 9/4/82 Ran LI~L 10,866-10,200. Ran in hole open ended to 10,860'. Displaced mud with 500 bbl. lease crude. Began running 3 1/2" production tubing. 9/5/82 Completed running 3 1/2" tubing at 10,417' as follows: *Ail gas lift mandrels are Mc~urry-Hughes, 3 1/2", 8rd b~D with 1 1/2" side pockets. I~,! LEN~ TOP @ BOITOM @ KB correction 1-jt 335 9.3# 8rd N-80 TBG 1-Otis 5 nipple, pos.4, 2.875 ID 47-jts 3~ 9.3# 8rd N-80 TBG *l-Gas lift ~,~drel 1-Pup 40 jts 3~ 9.3# 8rd N-80 TBG *1 Gas lift bi3ndrel 25 0 25 31.65 25 56.65 1.16 56.65 57.81 1477.13 57.81 1504.94 8.61 1504.94 1513.55 2.42 1513.55 1515.97 1236.63 1515.97 2752.60 8.65 2752.60 2761.25 RECEIVE JAN2 1 BB2 Alaska Oil & Gas Cons, Commissioa Anchorage 1-Pup 2.32 2761.25 2763.57 32-jts 3~ 9.3# 8rd N-80 TBG 978.89 2763.57 3742.46 *l-Gas lift ~-.~ndrel 8.64 3742.46 3751.10 1-Pup 2.35 3751.10 3753.45 24-jts 3~ 9.3# 8rd N-80 TBG 738.55 3753.45 4492.00 *l-Gas lift Ii~ndrel 8.64 4492.00 4500.64 1-Pup 2.36 4500.64 4503.00 26-jts 3~ 9.3# 8rd N-80 TBG 799.75 4503.00 5302.75 *1 Gas lift b~ndrel 8.59 5302.75 5311.34 1-Pup 2.32 5311.34 5313.66 16-jts 3~ 9.3# 8rd N-80 TBG 494.57 5343.66 5808.23 *l-Gas lift Mandrel 8.65 5808.23 5816.88 1-Pup 2.30 5816.88 5819.18 9-jts 3~ 9.3# 8rd N-80 TBG 277.96 5819.18 6097.14 *l-Gas lift ~ndrel '8.57 6097.14 6105.71 i-Pup 2.21 6105.71 6107.92 13 jts 3~' 9.3" 8rd N-80 TBG 400.91 6107.92 6508.83 *l-Gas b~ndrel ' 8.60 6508.83 6517.43 1-Pup 2.37 6517.43 6519.80 l18-j ts 3~ 9.3# 8rd N-80 TBG 3640.68 6519.80 10160.48 *l-Gas lift ~.i~ndrel 8.66 10,160.48 10,169.14 1-Pup 2.23 10,169.14 10,171.37 1-jt 3~ 9.3# 8rd N-80 TBG 31.23 10,171.37 10,202.60 1-7 5/8 Ba~ker FHL Packer 6.90 10,202.60 10,209.50 1-Otis Position 2 S Nipple 1.67 10,209.50 10,211.17 l-X-0 8rd BX X Seal Lok Pin .75 10,211.17 10,211.92 7-jts 3~ 9.3# Armco Seal Lok N-80 203.37 10,211.92 10,415.29 1-X-O Seal~ Lok Box X Butt. Pin .85 10,415.29 10,416.14 1-3~" Baker Shear Sub .78 10,416.14 10,416.92 landed @ 10,416.92 pipe in hole 10,391.92 Pressured up tubing to 2200 psi and set packer at 10,203'. Pressured up to 2200 psi and sheared ball seat. Tested annulus to 2000 psi - o.k. Set back pressure value and nippled down BOPE. Nipple up tree and tested to 5000 psi - o.k. Valve released rig 12:00 noon 9/5/82. Rigged down. 9/6/82 Rigged down. 9/30/82 Rigged up Dresser Atlas and ran in hole with 2 5/8" Slimkone Hollow Carrier gun. Encountered an obstruction at 6000'. Attempted to work past obstruction without success. Stuck perforating gun at 6000'. Attempted to free gun without success. RECEIVEI) JAN2 11983 Alaska Oil & Gas Cons~ Comm~ss~o,~ Anchorage 10/1/82 Rigged up pulling tool and rigged down lubricator. Pulled out of rope socket. Ran in hole with overshot and jars. Engaged fish and jarred twice - fish canto free. Pulled out of hole. Perf. gun covered with asphaltine. 10/4/82 Dresser Atlas ran in hole with a 2 5/16" combination gauge ring-impression block. No &rag was encountered until the tool string stopped at a solid obstruction at 6000'. A collar strip was recorded and tied back into the tubing tally- which identified the obstruction as being in the gas lift manclrel at 6097'. 10/5/82 Attempted unsuccessfully to retrieve gas lift dumny at 6097'. 10/7/82 Dresser Atlas perforated 4 HPF, 0° phasing, with a 2 1/8" Slimkone Hollow Carrier gun.~ 10,726' -10,732' DIL. RECEIVE[} JAN2 1 1383 Alaska 0il & ~as Cons~ Oommi's~io. Anchorage TR~\NSMITTAL AND ACKNO~EDGEb[ENT OF RECEIPT OF MATERIkL - (ALASKA) .'THE' FOLLOWIMG IS A LIST OF MATERIAL ENCLOSED HEREIN. CIIECK A2~D ADVISE I}~5~DIATELY. PLEASE COMPTuNY · · -" RUNS . ,. . · . · · SCALE XEROX SEPIA ....... N INDUCTION ELECTRICAL LOG DUAL INDUCTION BOREItOLE CO}fPENSATED SONIC BOREIiOLE COMP. SONIC w/caliper BOi~EItOLE ,il.:~J~ C[ 'B ~'~:1, ~ C~'' BOREHOLE TELEVIEWER' .' CONTINUOUS DIPI.~TER'- High Res. CD}[- POLi%{OG PLOT CE}~NT BO~ LOG-~C~T;~ CASING COLLAR LOG - Perf. Rec. CO}~ENSATED FOPd.~TION DEN. CO}~ENSATED NEUTRON FOP~TION ~ALYSIS LOG FO~LaTION DENSITY LOG F F FO~.~TION TESTER FOm~b%T~ON FACTOR F F. .-... MICRO- LOG ' ' MI CROLATEROLOG ~D LOG NEUTRON LOG PROXIHITY MICROLOG ~WA Co~mA~zso~ S~,~',~D SOIIIC CO:.LPLETION REPOiIT DIRECTIONAL SURVEY CORE DATA SAFO\B,~D TABULAR LISTING Received and checked by: BLUELINE Gas Cons. ~mmission ~chorage · / NE CORNER SEC. 8 (Protracted) SCALE 1" = 50' SCU 32-8 .x±st- ~ SCU 31-8 New Well U.T.M. Coordinates ~/Center 20" casing NE 22,088,498-25 2,017,877 40 · ~ ........................... N.T.S.1968' Z ;/~ SCU 33-8 NOTES: ~ Exist. This survey and all data shown is based on t~e existing Wells SCU 33-8 and 32-8 with the related surveys by C. A. Herschback, R.L.S., dated March 7, 1973. Top gravel pad elevation is 128.5 ft. WELL SURVEY OF $CU 31-8 PREPAR£O FOR CHE~/RON U.S.A. Inc., OPERATOR SURFACE LOCATION: 1902 Ft. South and 1968 Ft. West from the NE corner of -- protracted Section 8, T7N, R9W, S.M., Alaska. Surveyed by; McLane & Associates, Inc Date of Survey, June 22, 1982 Suggested form to be inserted in each "Active" well folder to check for timely compliance with our regulations. O~e~at6~',' Wel 1 Name-and Number Reports and Materials to be received by: //--- / ~--~ ' Da~e v Required Date Received Remarks Completion Report Yes . ~ ~ ...... _Samp les ./iT' 1../.. " ......... ~:3~ ....... ~:~tZ:¥,. - ~,~::~:~'<'~:'Z:;'' '''~' Core ~scription Registered ~ey 'Plat ~/~ _ Inclination S~ey · ,, , ...~ ~o~ ~~ .... 7,x_h ..... Drill St~ Test Re~s ... Pr~u~on T~t Re~rts ., Digitize, ~ta ......... . WELL COMPLETION OR RECOMPLETION REPORT AND LO 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number Chevron U.S.A. Inc. 81-99 3. Address 8. APl Number P. O. Box 7-839, Anchorage, Alaska 99510 50-133-20344 4. L~o~a~tjaon of well a~t~¥_rf~ce 9. Unit or Lease Name ~ S & ~9/J~r, w of the N.E. Cor., Sec.8, T7N, R9W, S.M. Soldotna Creek Unit At Top Producing Interval 10. Well Number 633' N & 578' E of Surface SCU 31-8 At Total Depth E,~', 11. Field and Pool 689' N & 660' E of Surface 1~13 'F~/c 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Swa.t~son River Hemlock 128' G.L. A-028997 I 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 16. No. of Completions 6-26-82 8-23-82 10-19-82 -- feet MSL 1 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set 21. Thickness of Permafrost · 10,783'TVD,10,904 10,860'MD-10,740 YES [] NO [] .-- feet MD -- TVD 22. Type Electric or Othei~'~Jogs Run DIFL,BHC/ACOUSTIC/GR/SP/CALIPER~ CBL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 94~ H-40 Surface 72 ' -- Driven 10 3/4" 40.5# K-55 " 3,383' 14 3/4" 1490 SX CL "G" 7 5/8" 33 7,26~ 4 S-95 " 10,.452' 9 7/8" 800 29.7 5 1/2" 209 N-80 10,246 10,902' 6 5/8" 86 SX (SQZ. LAP witlz 1034 SX) 24. Perfo?ati0.ns open to Production (.MD+TVD of Top and Bottom and - 25. TUBING RECORD . interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) H-10 3 1/2" 10,417 10,203 10,726 - 10,732 MD-4 HPF - .33 10,609 - 10,615 - TVD 26.' ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED : · - · 27. PRoDucTIoN TEST Date First Product on .. I Method of Operation (Flowing, gas lif~, etc.) · ,., .' ,, . ,, ,; , ,,, · . ,. ,: , . , 10-19-82 'I Gas Lift .. Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO 10r,.11~.82.. 4 . TEST.:PERiOD I~.. 1113 2.9.38 . 23 SP 26,-40 FIowTubi~g . ·CasingPr~essure - CALCULATED,,k OII"-BBL GAS-MCF. ii WATER-BBL OiL GRAVITY-APl (corr). 'Press. '40.0 :: ~-.-. 24-HOUR. RATE . . 28. .CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Sidewall samples taken - Data submitted separately. 'd r - + ,r ,-'r,,-,, ) ' . RECEIYEI) NOV 0 8 1982 Nask~ Oil & Gas Cons. Commission Form 10-407 ~ Submit in duplicate Rev. 7-1 ~80 CONTINUED ON REVERSE SIDE NAME H-1 (Top Hemlock) MEAS. DEPTH 10440' TRUE VERT. DEPTH 10331' Include interval tested, pressure data, all fluids recovered and gravitY, GOR, and time of each phase. None 31. LIST OF ATTACHMENTS 32. I hereby certify t~rue and correct to the best~°f my knowledge Supt. 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 i¢iterval (multiple completion), ..so state in item 16, and in item 24 show thi~ 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: Atta'.ched 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". Form 10-407 LOCATED IN THE APPENDIX WFL IPR LOG CALIPER SURVEY VOLAN CURVE DATA STRATIGRAPHIC HI GH RE S O LUTION DIPMETER OTHER: TO: Receipt of the following material RE- which was transmitted via is hereby acknowledged. QUANTITY DESCRI PT I ON I 9 ,,. .,, q 9 - ..5'C u ?/-~' DATED: Copy sent ¥~s ~ to sender NO MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. Drilling well,~ Workover operation [] 2. Name of operator 7. Permit No. Chevron U.S.A. Inc. 81-99 3. Address P. 0. Box 7-839, Anchorage, Alaska 99510 4. Location of Well at surface · 1850' S & 1950' W of the N.E- Cor., Sec. 8, T7N, R9W, S.M. 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 128' G.L.I A-028997 8. APl Number 5o-133-20344 9. Unit or Lease Name Soldotna Creek 10. Well No. $CU 31-8 11. Field and Pool Swanson River Hemlock For the Month of September ,1982 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Squeezed 5 1/2" liner lap with 30 SX Class G. Tested to 3000 Displaced mud with lease crude. Ran 3 1/2" tubing to 10,417' N.U. X-mas tree. Released rig 9/5/82. psi - o.k. N.D. BOPE - 13. Casing or liner run and quantities of cement, results of pressur9 tests 14. Coring resume and brief description 15. Logs run and depth where run CBL VDL 10,866 10,200 CNL 10,866- 10,200 1 6. DST data, perforating data, shows of H2S, miscellaneous data 17. I hereby certify that thef~ue and correct to the best of my knowledge. SIGNE~' ~--'~'/' ~---~~-~'/~--//TITLE/~/"r~~/ Area Operations Supt. DATE /'~/'~,~l/d° ~ NOTE--Report on this form is requiC~-d for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate Rev. 7-1-80 SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL COMPLETED WELL [] OTHER [] 2. Name of Operator Chevron USA Inc. 3. Address P. 0. Box 7-839, Anch., Ak 99510 4. Location of Well 1850'S & 1950'W of the NE Cor., Sec. 8,T7N,P,9W, S.M. 5. Elevation in feet (indicate KB, DF, etc.) 128'G.L. 12. 6. Lease Designation and Serial No. 7. Permit No. 81-99 8. APl Number s0-133-20344 9. Unit or Lease Name Soldotna Creek Unit 10. Well Number SCU 11. Field and Pool Swanson KLver-HemIoc~ A-028997 ' Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: (Submit in Triplicate) Perforate ~ Alter Casing [] ~ Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other ~ Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). It is proposed to test and complete well SCU 31-8 as fOllows: (Work to conmence upon receipt of approval) 1. Perforate and test H-10 sand from 10,726'-10,733'. 2. If' the H-10 sand is unproductive - isolate with a thru-tubing bridge pl~. If the H-10 is productive (low GOR and water cut)~- retain. 3. Perforate and test H-9 sand from 10,695' -10,703'. 4. If the H-9. sand is unProductive - isolate with thru-tubing bridge plug TM. If the H-9 is productive - retain. 5. Perforate and test lower H-8 sand from 10,664'-10,672'. v 6. If the lower H-8 sand is unproductive - isolate with a thru-tubing bridge plug. If the lOWer H-8 is productive - retain. 7. Perforate and test the upper H-8 sand from 10,616' -10,634'. / 14. I he~c~rti~ t~at the foregoing is true and correct to the best of my knowledge. S~g.ed /"~" 'O~~ m~t,e ~ea ~g~eer o.,e '9/16/82 . The spa. p?~or c~mi.i~use Conditions~ Ap~ova~ if any: Approved '?o~¥ Returned 0~;1,~ ~;'~[ SIGNED BY LOHNIE C. S~illli By O~d~of Approved by COMMISSIONER the Commission Date Form 10~403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate STATE OF ALASKA ~Z~ ALASK/~"' .L AND GAS CONSERVATION C(" 1MISSION ~ MONTHLY REPORT OF DRILLING AND WOIrlKOVER OPERATIONS 1. Drilling well ~ Workover operation [] 2. Name of operator 7. Permit No. Chevron U.S.A. Inc. 81-99 3. Address 8. APl Number P. 0. Box 7-839, Anchorage, Alaska 99510 50-133-20344 4. Location of Well at surface 1850' S & 1950' W of the N.E. Cor., Sec. 8, T7n, Rgw, G.L. I - A UZ891/ 9. Unit or Lease Name Soldotna Creek Unit 10. Well No. SCU 31-8 11. Field and Pool Swanson River - Hemlock For the Month of August ,1982 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud.date, remarks Dri 11 ed from 9371 ' -1 0,535" Took SWS. ran 7 5/8" CSG. to 10,452' and CMT. with 800 SX. Class "G". Lost W.L. tools in hole-recovered same. Drilled cmt. 8394-10,434'-tested 7 5/8" CSG. to 3000 psi-o.k. Drilled cmt.'~ 10,434-10,449'. Washed to 10,535' Drilled shoe 10,449-10,452. Drilled 6 5/8" hole 10,535-10,904' T.D. Logged. Took S~S. ran 5 1/21' liner-lO,902'-lO,246' and cmt with 86 SX Class "G". Cleaned out CMT. to 10,746'. Liner lap leaked.. Drill~ to i0,856'. SQZ lap i:ou~ times with a total of ZO0.4 SX without success. At month_ 13. Casing or liner run and quantities of cement, results of pressure tests SqLIP~eZ, 3_i'lg J-ap J-it:th t3_h'le. 7 5/8" casing CMT. with 800 SX. Press test to 30.00 psi - o.k. 5 1/2" liner CMT. with 86 s×. 14. Coring resume and brief description 10,378' - 10,877' (SWS at intervals) 15. Logs run and depth where run DIL-BHC-SONIC-SP 10,533-3385 CBL-1 0,41 5-8500' ~ DIFL/SP/GR/BHC/Acoustic Log/CAL/SP/GR CDL/CNL/GR 10,902'-10,452' 1 6. DST data, perforating data, shows of H2S, miscellaneous data .., SEP 1 i982 Gas [~ons. Comrn,~ssior~ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. DATE NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate Rev. 7-1-80 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 Porcupine Drive Anchorage, Alaska 99501 (907) 279-1433 TO: RE: Receipt of the following material which was transmitted via is hereby acknowledged: QUANTITY DESCR I PT ION RECEIVED: DATED: Copy sent to sender YES-~ NO X STATE OF ALASKA ~ MO~---NTHLY A~ASKA( _AND GAS CONSERVATION C(~~ MISSION REPORT OF DRILLING AND WORKOVER OPERAT Drilling well Workover operation [] 2. Name of operator CHEVRON U.S.A. INC. 3. Address P.O. BOX 7-82t9, ANCHO~GE, AK 99510 4. Location of Well at surface 1850' S, 1950' W of the N.E. Corner, Section 8, TTN, Rgw, S~M. 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 128I GLI A-n2R997 7. Permit No. 81-99 8. APl Number line SOLDOTNA CREEK UN IT 10. Well No. SCU 31-8 11, Field and Pool SWANSON RIVER HEMLOCK For the Month of J u ] y 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Ran and cemented lO 3/4" CSG at 3383I. N. U. and tested BOPE. surveyed from 33901-9371'. Drilling at 93.71' at month's end. Drilled and 13. Casing or liner run and quantities of cement, results of pressure tests 40.5#, K-55 10 3/4" CSG at 3383' - Cemented with 1490 sx cl "G". 14. Coring resume and brief description 15. Logs run and depth where run 1 6. DST data, perforating data, shows of H2S, miscellaneous data ,AUG .. 6 982 Alaska Oil S Gas Cons. CommisSion Anchorage 17. I hereby certify that the foregoi~,q~ true and correct to the best of my knowledge. ~ Area Operations Supt. 'SIGNED ~ ' "'~' /?~~'2,~'~_. ~ ~.,~ITLE ...... -- __ __---- DATE NOTE--Report on this form i~ required for each calendar month, regardless of the status of operations, and must be flied in duplicate with the A aska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 ' Submit in duplicate Rev. 7-1-80 (' STATE OF ALASKA [ ALASKA 0IL AND GAS CONSERVATION C(},,,MISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL COMPLETED WELL [] OTHER [] 2. Name of Operator 7. Permit No. Chevron U. S. A. :[nc. 81-99 3. Address 8. APl Number P. 6. Box 7-839, Anch., AK 99510 50- 133-20344 4. Location of Well 1850'S & 1950' W of the NE Cor., Section 8, T7N, R9W, S.M. 5. Elevation in feet (indicate KB, DF, etc.) 128' G.L. 12. I6. Lease Designation and Serial No. A-028997 9. Unit or Lease Name Sold0tna Creek Unit 10. Well Number SCU 3~-8 11. Field and Pool Swanson River-Heml ock Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] , Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans ~ Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). /' It is proposed ~the T.D. of Well SCU 31-8 from lO,746'TMD, ~0,592'TVD to lO,950'TMD,~; '~ ~p 75~~''' i982 Alaska Oil & Gas Cons. CoinmJssior~ Anchorage 14. I hereby certify that the foreg~ true and correct to the best of my knowledge. ' Signe~. ~?~z~---"~t--'~/ Title .~.?e~ Operations Supt. The space below for Commission use Date Conditions of Approval, if any: Approved.,-o,~y Returned COMMISSIONER By Order of ...... the Commission Submit "1 ntentions" in Triplicate and "Subsequent Reports" in Duplicate MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS Drilling well I-~ Workover operation [] !. Name of operator 7. Permit No. Chevron U.S.A. Inc. 81-99 3. Address 8. APl Number P.O. Box 7-839, Anchorage, AK 99510 50-133-20344 4. Location of Well atsurface 1850tS, 1950'W of the N.E. Cor., Section 8, T7N, R9W, S.M. 5. Elevation in feet (indicate KB, DF,.etc.) I 6. Lease Designation and Serial No. 128' G.L.I A-028997 9. Unit or Lease Name Soldotna Creek Unit 10. Well No. SCU 31-8 11. Field and Pool Swanson River Hemlock For the Month of. June ,19 82 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Drove 20" 94~ H--40 CSG to 72' N.~. 20" BOPE. Spudded 6/26/82. Drilled and surveyed 10 3/4" hole to 3390'. Circ. and Cond. for lo~s. ran DIFL/GR 3375' (LTD) to surface preparing to run 10 3/4" CSG. 13. Casing or liner run and quantities of cement, results of pressure tests Drove 20" 94~ H'40 CSGo to 72'. 14. Coring resume and brief description None 15. Logs run and depth where run DIFL/G~ - 3375' ..(LTD) to surface 1 6. DST data, perforating data, sh6ws of H2S, miscellaneous data None JUL ,~ 6 ~982 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ",,wlorage -~,,l~/88~o~ SIGNE~ ' _ ..... Area Operations Supt. DATE 7/1/82 NOTE--Report onth~s form ~s q h regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10~04 Submit in duplicate Rev. 7-1-80 June 29, 198P. ~,~r. ~';illiara Bauer Area Operations Superintendent Chevron U.S.A. Inc. P. O. Box ?-839 Anchorage, Alaska 99510 Re: Soldotn. a Creek Unit, SCU 31-8 Dear Mr. Sauer: Fern 10-403 (SUI~L~RY NOTICE AND RBPORTS O1~ WBLLS), for S~ 31-8, dated .June 17, 198Z is returned. This is a ~est fo~ a oha~e In bott~hole looation for S~ 31-8 ~ieh has been impl.e~nted by a Form 10-401 (P~MIT TO ~ILL). ~e Fo~ 18-401 was the prope~ vehiole for this chan~e. Consequently, the Fo~ 10-403 is returned uns i ~ned. Sincerely, Lonnie C. Smith Commi ss toner Eno. l o su re LCS ~be ~une 15, 1982 ~fr. l~tl lia~ Sauer Area Operations Suporintendent Chevron U.S.A. Inc. P. O. Box ~-839 Anchorage, Alaska 99510 Be: Soldotna Creek Unit SCU 31-8 Chevron O.S.A. Ine. Per. it No, 81-99 Sur. Loc. 1850'S, 1950tW of ~B e~ See 8, TTN, Bg~, ~. ~t~ole Loc. 1260 ~8, 1350'W of NE er See 8, TYN, 29W, SM. Dear Mr. Sauer= Enclosed is the approved revised application for permit to drill the above referenced The provisions of the cover lette, r, dated October 5, 1981, aeec~panytng the original appr'oved permit are in effect for this revision. Very truly yours, C. V. Chatterton Cbs i rumn of BY ORDeal. OF ?;-;~ .CDM~m.~fAu Alaska Oil and Gas ~onse~a~on--~~ssion Eno 1 o sure er: Department of Fish a G~.~e, Habitat Sect ion w/o encl. Department of flnvironmental Conservation w/o encl. Robert Richey, Kenai National ~'il. dlife Refuge ~/o encl. CVC:be GEOLOGICAL JUSTIFICATION SCU 4-2L~8 is an H-8 sand development well on the west flank of the Soldotna Creek nose. This'location represents an on strike adjustment of the bottom hole location of undrilled 1981 budget well SCU 31-8 A theoretical sweep .o envelope study indicates the adjusted location will iower the risk of premature gas break-through and thus potentially increase ultimate reserves. The well will be directionally drilled from'the same surface location,£the SCU 32-8 pad. Stratigraphy and structure are well documented. Approximately 75' of oil effective 8 sand are anticipated with an average porosity of 21%. Incremental reserves assigned to the well are 680,000 bbl., using 337 bbl/acre foot recovery factor. The well will be essentially on strike with SCU 24-5, the only other 8 sand prodUce~.in this block. SCU 24-5 has a cumulative production of 1.8M bbls of oil, an IP of 2000/4/1100 O/W/G, and is cur- rently producing 387/103/15,891. SCU is designed to increase recovery in the H-8 sand in this block by producing currently unrecoverable reserves. The well will be drilled through the H-lO sand for oil-water interface control an&a possible secondary objective. REVISED PERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL ~] REDRILL [] DEEPEN [] lb. Type of well EXPLORATORY [] DEVELOPMENT OIL [~ DEVELOPMENT GAS [] SERVICE [] STRATIGRAPHIC [] SINGLE ZONE [] MULTIPLE ZONE [] 2. Name of operator Chevron USA Inc. 3. Address P. O. Box 7-839, Anchorage, AK 99510 4. Location of well at surface+ 1850' S & 1950' W from the NE Cor., Sec. 8, T7N, R9W, S.M. At tOp of proposed producing interval -Fl 210' S & 13 00' W of the NE Cor., Sec. 8, T7N, R9W, S.M. At tota~ depth +__1260' S & 1350' W from the NE Cor. , Sec. 8, T7N, R9W, S.M. 5. El~.vation in feet (indicate KB, DF etc.) 128' GL I 6 . Lease designation and serial no. · A-028997 9. Unit or lease name Soldotna Creek Unit 10. Well number SCU 31-8 11. Field and pool Swanson River Hemlock 12. Bond information (see 20 AAC 25.025) Type Nationwide Surety and/or number SL 6205862 Amount $150 r 000 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 15. Distance to nearest drilling or completed app. 16.5 mi. fr. Kenaimiles 1900 feet 32-8well 52 feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 18. Approximate spud date 10,746 MD, !:0 ' 592TVD feet 1120 6/26/82 19. If deviated (see 20 AAC 25.050) 120. Anticipated pressures KICK OFF POINT 7825' feet. MAXIMUM HOLE ANGLE 20 Ol (see 20 AAC 25.035 (c) (2) 3 _R0 0 psig@~ Surface 6500 psig@ 9000 ft. TD (TvD) Proposed Casing, Liner and Cementing Program SIZE Hole Casing Weight See 22. Describe proposed program: CASING AND LINER SETTING DEPTH MD TOP TVD M D BOTTOM TV D I I I QUANTITY OF CEMENT (include stage data) We propose to drill SCU 31-8 per attached program RECEIVED JUN 2 4 1982 Alaska Oil & Gas Cons. Commission Anchorage 23., hereby cert~/~hat t~ f/~egoing is true and correct to the best of my know)edge SIGNED _ ~ -- TITLE Area Operations Supt DATE 6/21/82 The space below f'"~r C'~m~ission use ~ _~ CONDITIONS OF APPROVAL Samples required Mud log required [~YES J~NO []YES Permit number APPROVED BY_ Form 10-401 Rev. 7-1-80 Approval date Directional Survey required APl number []NO 50- SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMM ISSl ON ER DATE by order of the Commission Submit in triplicate PROPOS ' , OR WELL OPERATIONS PRO'316-1 · Field: 'Swanson River. Property and Well: Soldotna creek Unit ~-8. Surface Location: Approximately 1,850 feet south and 1,950 feet west from the northeast corner of Section 8, T7N, R9W. SB~.I. Bottom Hole Location: Approximately 1260' south and 1,350' west from the northeast corner of Section 8, T7N, R9W. Elevation: 128 feet est. G;~L. Estimated'145 feet K.B. (Brinkerhoff ~54). BlOwout Prevention Considerations: -.. Potential Problems a~ Gas'and water entries: Gas sands may be encountered at any depth below the shoe of the surface casing. High pressure water'sands are known to exist between 6,000 and 10,000 feet. The surrounding wells were drilled with 95-98 pcf mud with no gas or water kicks. Hemlock zone static reservoir pressure is 4400 psi. Well SCU 341-8 is currently injecting gas at 5600 psi. This represents a gradient of .52 psi/ft, or a mud weight of 75'pcf to equalize. Gas and water entries can cause severe hole problems and the mud system should be carefully monitored at'all times. e B. Lost Circulation: No losses have.been experienced during drilling operations in surrounding wells except for a short period of time at 6,800 feet in SCU 341-8. Lost circulation has occurred in Q~her SRF wells while drilling the Hemlock '. with 98 pcf mud. In SCU 42-8 casing wi'll be cemented above the Hemlock zone and the mud weight reduced to drill to T.D. Lost circulation materials to be kept on hand at all times. Precautions: A~y kicks should be handled by normal procedures. Drilling crews should.~be made aware of these methods prior to spuddinq. Kick ~nd BOP drills should be practiced a~ regular intervals and noted on the tour sheets. An adequate supply of weight material should be at the well site at all times. . Maximum Anticipated F6rmation PreSSure: 6500 ps~ in high pressure water sands above 10,000 feet. " 3. Maximum Anticipated Surface pressure: 3800 psi. 4. Blowout Prevention Equipment: ClaSs III 5000 psi and 10-3/~" and 7-5/8" casing. Estimated Depths ' .i~,~R~'~MD -.%0,592;TVD ,. RECEIYEi). JUN 2 ]982 Alaska Oil & Gas Cons. CommJssiorl Anchorage .o ._ 1[ Drive 20" conductor pipe to ~0 feet or aS deep as possible during rig up. .. 2. Drill for 10-3/4" casing to ~,~00 +_ feet. Maintain drilling fluid per ~ attached drilling fluid program. At 3,400 feet, condition hole for logs. Take ~ gallon sample of mud returns prior to pulling out for log. Run Schlumberger Dual Induction log with SP from effective depth to shoe of conductor. Use linear " scale for 2"/100' track and logorithmic scale for 5"/100' track. Use 10 MV scale for SP and 0-50 ohm-meters for linear resistivity scale. Development Geologist to witness. All logs to be taped. 4. Cement 10-3/4", 40.5~/feet, K-55 Buttress casing at 3,4'00 feet.' . e e . . a. Use float shoe and stab-in duplex collar two joints off bottom. . Centralize bottom five joints. Cement. through shoe in one stage with sufficient Class "G' cement pre-mixed with 2.4% gel by weight of water to obtain returns to surface.. If cement returns are not received at the surface, do a top~ j ob. ~ De NOTE: Class "G" cement with pre-mixed gel at 2.4% by weight of water: Yield - 1.86 cU~- ft./ sx. cmt. · Water requirements - 1.36 cu. ft./sx, cmt. Gel requirements - 1.5 lb/cu, ft. of water. J!i~,!~ ~i'~ ~'~" .t,JS~'~C Slurry weight - 98 pcf. ,~b.~!~:~ t,,~ ~..~.~.: (?::r~.~ . H~ve s~ge aoll~r on loa~on ~n e~se 'los~ a~rgul~o~ oag~rs w~z~.,,- drilling ~op hole. .-' Cut off 10-3/4" casing bel0~ the' top of the cellar (ground level) to allow the top flange of the tubing head to .be above ground level after completion. Install 10" - 5000 psi, 10-3/4" SOW c~sing~ead~___. Test lap weld to 2500' psi. Install Class III, 13-5/8" -5000 psi BOPE as per the attached BOPE design. Test BOPE, kill line, blow line, and manifold to 5000' psi per State Regulations 20 AAC 25.035. Alaska Oil & Gas Conservation Comission and/or U.S.G.S. to witness BOPE tests. Drill out cement in 10-3/4" c,asing to ~ithin 10 feet 6'f the shoe2: Pressure' test casing to 2500 psi. If test is OK. drill out shoe. Drill 9-7/8" hole"~'-a true vertzcal dep'th of 10,422 feet, estimated 10,563 feet M.D., estimated top of He.ar, lock sands ~s follows: - ~' ae Be C~ Follow mud specifications per the attached mud program. Take Single shot surveys to estimated K.O.P. at a minimum of 480 feea, or at shorter intervals if required.. .: · Beginning at approximately 7,825 feet, K.O.P., build 2%°/100' to 20© along a c.~urse of North 46© East. Hold 20©. angle and course to target. "?~rget is top of the H8 sand at -10,435 V.S.S. at a location of 580 feet North and 630 feet East of the SCU 33-8 surface location, or approximately 860' N46°E of surface location.) "'10. At effective dep~''f' '~Condition hole for logs. Tak~~'~'' gallon sample of mud returns prio~ c° pulling out for log. Run the~following Schlumberger logs: ae ~Dual Induction log with SP and GR from effective depth to shoe of 10-3/4" casing. Use linear scale for 2"/100 feet track and logorithmic scale-for 5"/100 feet track. Use 10 MV scale for SP and 0-50 ohm-meters for linear resistivity scale. Use 0-100 GR scale. Bo BHC - Sonic log - SP from effective depth to shoe of 10-3/4" casing. Use 50-150 microsecond transit time scale. C. Have FDC-CNL tool, sidewall sample gun, and TDT tool on location. Shoot S.W.S. as directed by Development Geologist. -._ D. Record all logs on tape. · 11. Drill ahead if indicated by log to set 7-5/8" casing shoe at t~p of Hemlock H-1 sand. (Approx. 10,563') 12. Run 7-5/~" casing as follows: a. Bottom: 2,200 feet 33.7/#ft. S-95 LTC Next: 3,320 feet 29.7#/ft. S-95 LTC Next: 1,900 feet 26.4#/.ft. S-95 LTC Next: 3,063 feet 26.4#/~t. N-80 Butt Top: 80 feet 33.7#/ft. S-95 LTC NOTE: For deeper casing depth add 33.7#/ft S-95 LTC on bottom as required. Bo Ce De Run standard ShOe and collar. Run stage collar at approximately 7,500 feet. % Centralize bottom 500 feet and above and below stage collar. Cement in tWo stages as~follows: (1) .Shoe job: Use sufficient Class "G" cement treated with 3/4% CFR-2 ... to reach.~near 8,500 feet. Mix to slurry weight of 118-122 pcf. (2) Stage collar: Use sufficient Class "G" cement pre-mixed with 2.1% gel, by weight of water, to lap into th? 10-3/4" casing at 3,400 feet. NOTE: Clas~ "G" cement~with pre-mixed gel at 2.1% by weight of water: Yield '~: · ~ - 1.680cu. ft/sx, cmt. Water requirements - 1.18 ft. /sx.cmt. Gel requirements - 1.3 lbs/ft, water. Slarry weight: - 102 pcf. JUN 2 4 982' Oil & Gas Cons. Commjssio~ 13.. R~move BOPE and land 7-5/8" casing. Install a 10" - 5000 psi Do55om ~±ange x 8" - 5000 psi top flange tubing head. Test secondary pack-off to 5000 psi. Install 13-5/8" - 5000 psi Class III BOPE. Test BOPE, kill line, choke line and· mani-fold to 5000 psi per State 'Regulation 20 AAC 25 035 Alaska Oil & Gas Conservation Commission and/or U.S.G.S. to witness test· 14. Drill out stage collar and cement to within 10 feet of 7-5/8" casing shoe. - 15. Run Variable Density - CBL-GR log from effective depth to above top of cement from stage collar job. 16. Based on CBL, squeeze for WSO above Hemlock as required. 17. Pressure test 7-5/8" casing to 3000 psi. 18. Condition mud weight to 70-72 pcf-._ · _ · ',19.. Drill ahead in 6-5/8" open hole to a true vertical depth of 10,781 feet . · estimated 10,939 feet M.D. Maintain.angle to intercept target at -10,445 VSS at a location 1,150 feet north and 200 feet west of surface location. · 20. Condition hole for logs. Take % gallon sample of mud returns ~rior to pulling out. for log. Run the following Schlumberger logs. A. Dual Induction log with SP and GR from T.D. to shoe of 7-5/8" ca~ing. Use scales in an intermediate log. B. BHC - Sonic log from T.D. to shoe of 7-5/8" casing. C. --FDC-CNL-SP~GR. De .. Take sWs as directed by Development Geologist. 21. Condition hole for 5%" liner. .. 22. Cement apprOximately 640 feet of 5%' 20# N-80 buttress casing at 10,939 feet ,, with sufficient densified (~22 pcf) Class "G" cement with 3/4% CFR-2 to ~ obtain returns above top of liner. ' ~. A. Use float shoe and float collar one joint above shoe. Be Ce ~'~1ow for 200 feet of special clearance couplings. ' .... '~ Equip liner with 7-5/8" x 5%" Burns liner hanger grooved ~or cementing. 23. Clean out cement to top of float collar. 24. Run Variable Density cBL-GR-C, CL log, Compensated Neutron log and TDT log from effective depth to above top of liner'hanger. Scales to be provided by Engineering R~presentative on location. 25. Pressure test 7-5/8" casing, .~.z x 7-5/8" ~ap, and 5¼ liner to 3000 psi. 26. Obtain WSO below base of H8 sand. ~ 27. Displace 7-5/8" casing and 5%" liner with lease crude. 28. Run 3%" completion string with single packer per supplementary program to be issued after logs have been run. 29. Remove BOPE and install x-mas tree. Pressure test tree to 5000 psi. o. 30. Perforate, through tubing, lowermost single sand indicating low GOR per supplementary program. . 31. Release rig, place well on production as directed. Oil' & Gas Cor~s, Oorr~r~ssio,,¢ .PROPOSAL FOR L"LL OPERATIONs PR0-316-A USED' AS A G0-111) CASING REQUIREMENTS AND PRODUCING EQUIPMENT WELL/LOCATION NO. FI ELD Swanson River TOTAL DEPTH 11000 ESTIMATED O/W/G /, CASING Gross Footage : Conductor ' 80' 3400' scu ~ j~- % METHOD OF PRODUCTION · /. EQUIP. FOR STEAM APl Size Weight 2 0" 9T,~ -.. 10<,3/4" 40.5~ Grade H---c-4 0 K-55 DATE 1/25 7/82 ESTIMATED SPUD DATE MAX. ESTIMATED SURF. PRESSURE INJ. PRODUCER Threads Couoling Computer Desian For: - Buttress Sheet T & C OKThis Well Buttress Standard Design For Field Surface Requires: Float shoe and model "B" st&bin collar, stage collar: Well No. Buttress. 15-10 3/4" x 15" centrolizers, 2-10 3/4" Max. DriftAngle " stop rings, Baker-Lok Water String".' Design based on mud density 95 lbs./cu, ft. and above max. surf. pressure · 2280"' 7 5/8" 33.7# S-95 8R LTC XO's: S-~5 butt box x 81{ pin 3320' 7 5/8"- 29.7~ S-95 8R LTC S-95 8t{ box x 'butt pin . 1900' 7 5/8" 26.4~ S-95 8R LTC 25 - 9 7/8" x 7 5/8" centrali 3120' 7 5/8" 26.4~ N-80 Buttress Cementing Ac10620' 7 5/8" 33.7~ S-95 Baker Model "G" differential fullup shoe and collar 29.7~ S-95 8I{ stage collar and plug for stage cementing. Liner 720" 5 1/2" 20~ .N-80 Buttress Type I special clearance - Hanger 5 1/2" x 7 5/8" 33.7~ Burns hanger groved for cementing Perforated ', to ', -'- . Mesh, Rows, Slots, Centers, CASING } '. ,.-.... UNITIZED HEAD: 5000 PSI CWP. Bottom Conn. 10 3/4" SOW Type KD / '. '.': II ~.i:?;..::: Top Conn. lQ" X 5000 API RJ flanqe '", 2 X 2 screwed .. . Fittings 1 - screwed 3000 psi qate valve, bull plug on other side CASING SPOOl TUBING HEAD 5000 PSI CWP. Bottom Conn. 10" x 5000 API RJ flange " Top Conn. B" x 5000 APl RJ fla~qe " Type Suspension "Boll Weevil" 3 1/2 EUE 8R up and down, bored for 3 1/2 Cosa? . TUBING '"' , Feet AP! Size Weiqh__~t Grade Threads- .T~ Remarks · .' 400 3 1/~" 9.3~ N-8~) . Armc0 sea'l-io~ '-'?' .... (Cross-overs, etc.) '._ .. Bottom ,.10400 3 1/2" 9.3~ N-80 8R EUE . Next 9-McMu.rry-Hughes 3 1/2" MHO-1.5 mandrels, EUE 8i{, non coated w/8 dummy valves-1 1/2" 1-Baker shear sub - 3 1/2" 1.5 XO 81{ box x seal-lok pin Seal-lok ap. cl. Total 1-Otis "S" nipple~ pos 2+ optional 2.875" ID ' " '. Tub!ng Catcher' ' " ~ type .... Csg. Size " Wt. Install at Packer 7 5/8" 33....7~ x 3 1/2_ ,, Baker FHLType with "EUE 8:R. "stroke at Other Fittings w/ rotational release with .~ wt. XMAS TREE 3" ·X 3" Arm 5000 PSICWP. Dwg. No. AP-C-174-0 and AP-C-175-0 Tubing Beans " Type __" '. Header " Arm PSI CWP. D~g: No. Stuffing Box " ~ Type. Polished Rod "x PUMP: " ' x Type at RODS: Grade__, 'of "; 'of .... of PUMPING UNIT. APl Size Type Max. S!r__oke "Set at "Stroke and Engine Motor HP Remarks - 15 i~ ,~ ~-~ , ~,~.- ,, ~::::~;:Pre'pared By ': ApprovedA~ea Supervis~~' ~' ¢~~¢"~' c'"Sr' Drlg' Engineerby ¢ ./,~_ - _. . JUN 2 4 .i.q~2_ _ M J Allison . ~ - ,,-, . ' ' ~ Drlg. ~upc , ~ ~j ~aSR 0il & Gas Cons, C0mmjssj0n c~[co 2~sK-22~'(4 '% ~ ,/ I B~K ~ - ~ ' · ' ~-~ ~.. cc X~ ' · ,_. PRO-316-A {~ Printed in U-q DRILLING FLUID PROGRAH - S£U SWA~ISON RIVER FIELD Basic Dr. illinq. Fluid System Medium treated l ignosulfo~ate mud.- Optimum Drilline..Fluid Properties Mud Properties To 10-3/4" From 10-3/4" CSG. · CSG. PT. CSG.PT. to 6,000' Mud type Reclaimed mud or ex- tended gel Extended gel From 6,000' to 7-5/8" CSG.PT. T~gnosulfonate From 7-5/8" . CSG.PT. TO T.[ L~gnosulfonat~ Weight - pcf .. Viscosity - sec/qt. API 68-75 · 45-200-(1) 70-75 35-45 75-100 (2) 70-72 43-47' 43-47 Fluid loss-cc API Plastic viscosity-cps Yield point - lb/lOOft. · pH '- ".. Cal cium-ppm - · .. · Solids content % vol. - · 18-24 8-12 8.5- 10.5 50 max. · 7-13 7-10 4-7 18-24 18-24 6-8 6-8 9-10 9-10 ._..50 max. 50 max. 13-25 · 6-10 · . · .Remarks · 1. 2. , High viscosity as required for surface drilling. - '. 100 pcf max{mum anticipated re~fiired mud weight. Raise mud weight to 93 pcf by 7,000 feet. · . · o Have high pressure - high' temperature dril'l~ng fluid test equipment on. hand after drilling out shoe o'f'7-5/8" casing. Make fluid loss tests at est/mated bottom hole temperature of 170 degrees F. · · · · o · P ECEiYE jUN 2 z~ i982 j. . October 5, 1981 Mr. R. W. Magee' Area Engineer Chevron U.S.A. Inc. P. O. Box 7-839 Anchorage, Alaska 99510 Re z Soldotna Creek Unit No. 31-8 Chevron .U.$.A Inc. Permit NO. 81-99 Sur. Loc.~ 1850'S, 1950'W of NE' cr Sec 8, T7N, R9W, SM. SM. Dear Mr. Magee ~ Enclosed is the approved application for permit to drill the above referenced well. Well samples and a mud log are not reguired. A directional survey is required. If available, a tape containing the digitized log information shall be submitted on all logs for copying except experimental logs, velocity surveys and dipmeter surveys. Many rivers in Alaska and their drainage systems have been classified as important for the spawning or migration of anadromous fish. operations in these areas are subject to AS 16.50.870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to commencing operations you may be contacted by the ~abitat Coordinator's office, Department of Fish and Game. Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Article 7 and the regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Control Act, as amended. Prior to Mr. R. W. Magee -2- Soldotna Creek Unit No. 31-8 October 5, 1981 commencing operations you may be contacted by a representative -of the Department of Environmental Conservation. To aid us in scheduling field work, we would appreciate your notifying this office within 48 hours after the well is spudded. We would also like to be notified so that a repre- sentative of the Commission may be present to witness testing of blowout preventer equipment before surface casing shoe is dril led. In the event of suspension or abandonment, please giw this offi=e adequate advance notification so that we may have a witness present. Very truly yours, Hoy H. ~amilton Chairman of BY ORDER OF THE COP~5~;SSION Alaska Oil & Gas Conservation Commission Eno lo sure cc~ Department of Fish& Game, ~abitat ~ection w/o encl. Department of Environmental Conservation w/o/encl. HHH~be Chevron Chevron U.SA. Inc. P.O. Box 7-839, Anchorage, AK 99510 · Phone (907) 279-9666 T. L. Perryman Area Operations Superintendent Production Department September 22, 1981 Mr. Blair Wondzell Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Mr. Wondzell' Requests for permits to drill wells S__~_U 13-9 and 31-8, Swanson River Field . ,L . were mailed to you in July 1981 Attached are proposed directional courses for those two wells. The drilling program sent with the "PERMIT TO DRILL" form did not include an equivalent mud weight test when drilling out the shoe of the 10 3/4" casing. Both programs have been amended such that an equivelent mud weight test will be performed upon drilling out the shoe of the 10 3/4" casing. Sincerely, T. L. Perryman MKR' dmw \ ~ I0001' MD 0~864' TVO a"'::~ ' "IPROPOSED DIRECTIONAL COURSE I S.C.U. 31-8 '~. · ' ~ELD I,,:,,~~ ::,: : ~d,,'E-.-~,&' ,...~-. _,.~.';...--,- t I I:::'...--I ~P-O-:~' WELL NO. ~'C SECTION HO. TRACT NO, ~ PROPOSED [] PRELININARY E::::] FI NAL WELL SURVEY Pro-312 8 COUNTY OF /~'C~'7C2 I CITY OF TOWNSHIP TA/ RANGE,, LOT NO, FI ELD on~ /9~-o' ~/~t ELEVATION: 6ROUND 12~'-~ CONCRETE HAT DERRICK FLOOR '" A LT E RN A T E OR S U R V E Y E D L O C A T I ON L'OCAT I ~ .... DES I GNAT I ON LOCAT I ON COORD I NATES HOVE RE)lARKS ..... ,,, ~,~o.~/, ~v ?2 oe~ ~oo. ~ ..... E 2_0/7 ~9~, ~7 _ .................... _ .......... ,, , ................. ....... ........ ,, ......... _ ................................ _ . ....... ,, NORTH SOUTH STATION "'EArl IIG DISTANCE '' SiNE COSINE' NoR;r'H' 8~uTH EA~'T' WEST _ ................... ................. , .... ......... · , ,, .... , .... C.C. DIV. ENGR. FILE P'IINT[D IN U. I. SURVEYOR Crr'~,q ,-,~vO?¢ NAINT, FRI41. DATE.?~ ,5-~-,,.~,? /.9~1 DATE #AINT. SUPT. DATE PR0.3t2 (2500.(:D, 1.58) September 14, 1981 Mr. T. L. Perryman Area Operations Superintendent Chevron U.S.A. Inc. P. O. Box 7-839 Anchorage, Alaska 99510 Dear Mr. Perryman~ We have-received your letter of September 8, 1981 requesting 1- the waiver of 20 AAC 25.035(b)(1) for the S~~ well. This letter will advise you that the Alaska Oil and Gas Conservation Commission has examined the evidence available and hereby waives the requirements of 20 AAC 25.035(b)(1) for the SCU No. 31-8 well. Yours very truly, ~arry W. Kugler Commissioner Chevron Chevron U.SA. Inc. P.O. Box 7-839, Anchorage, AK 99510 · Phone (907) 279-9666 T. L. Perryman Area Operations Superintendent Production Department September 8, 1981 Request of Waiver of 20 AAC 25.035 (.b)(1) - Surface Hole Diverter System Mr. Holye Hamilton, Chairman Alaska Oil and Gas Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Si r: Chevron U.S.A. Inc. requests a waiver of your requirement of installing a surface hole diverter system at Well SCU 31-8, Swanson River Field. Following is a summary of surface holes drilled from the same pad that SCU 31-8 is to be located. DRILLING FLUID GAS OR WELL NO. DEPTH (FT.) DENSITY OIL SHOALS SCU 32-8 3014 86 PCF NONE SCU 33-8 3335 76 PCF NONE SCU 34-5 2035 80 PCF NONE ~/e believe past experience justifies subject waiver. An early reply will be appreciated. T. L. Perryman MKR:sjb RECEIVED ,~laska Oil & Gas Co,,~s. Commi$$i~r~ ., Anchorage Chevron Chevron U.SA. Inc. P.O. Box 7-839, Anchorage, AK 99510 · Phone (907) 279-9666 T. L. Perryman Area Operations Superintendent Production Department August 24, 1981 PERMIT TO DRILL NEW WELL SCU SWANSON RIVER FIELD Mr. Hoyle Hamilton Chairman Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Hamilton: Per your request, please add to the drilling program accompanying our request for Permit To Drill (20 AAC 25.005') SCU 31-8 dated JulY 2, 1981, the following: Surface holes have been drilled from the SCU 31-8 location pad for two wells as follows: Well No. .Depth Drilling Fluid Density. Oil or Gas Show SCU 32-8 3,024' 80-91 PCF None SCU 33-8 3,342' 76 PCF None T. L. Perryman : DGR: s j C. o~. Cor~. /laCb°rage STATE OF ALASKA C-(. ALASKA ,- AND GAS CONSERVATION C MISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL C~ lb. Type of well EXPLORATORY [] SERVICE [] STRATIGRAPHIC [] REDRILL [] DEVELOPMENT OILJ~] SINGLE ZONE [] DEEPEN [] DEVELOPMENT GAS [] MULTIPLE ZONE [] 2. Name of operator Chevron U.S.A. Inc. 3. Address P. 0. Box 7-839, Anchorage, Alaska 99510 ___ 4. Location of well at surface 1850' South and 1950' West from the 9. unit or lease name Northeast corner of Sec. 8, T7N, Rgw, S~&M Soldotna Creek Unit At top of proposed producing interval 10. Well number 31-8 Attota, depth 700' South and 2150' West from the Northeast ~.Fie~dandpoo, corner of Sectinn R.. 7-''; /' ~ q IA/, ~/Y%, ~ Swanson River 5. Elevation in feet (indicate KB, DF/etc.) / '6.'Lease designation and s~l no. Hemlock 128 GL A-028997 12. Bond information (see ~0 AAC 25.025) Type Nationwide Surety and/or number SL 6205862 Amount$150,000 . 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 15. Distance to nearest drilling or completed ADD. 16.5 miles from Keff&~s 1900 feet well 21-8 1150 feet 16'. 15roposed depth (MD & TVD) 17. Number of acres in leaser 18. Approximate spud date 10841 TVD 11058 MD feet 1120 12/1/81 19. If deviated (see 20 AAC 25.050) 120. Anticipated pressures 3800 psig@ Surface KICK OFF POINT 7000 feet. MAXIMUM HOLE ANGLE 21 oI (see 20 AAC 25.035 (c) (2) 6500 , psig@ 9~J00 ft. TD (TVD) 21 Proposed Casing, Liner and Cementing Program · SIZE CASING AND LINER SETTING DEPTH QUANTITY OF CEMENT Hole Casing Weight Grade Coupling Length MD TOP TVD MD BOTTOM TVD (include stage data) I ~ ' Se~ attac~ed pro.~ram ~ I .. I 1 · · I i ~ I 22. Describe proposed program: We propose to drill well SCU 31-8 per the attag~i~o~r~D RECEIVED' ~ JUL 0 7 1981 Petroleum B. evenue Division Alaska Oil & Gas Cons. Commission Anchorage 23. I hereby certify that the foregoing is true and correct to the best of my knowledge SIGNED TITLE Area Engineer,~.i-'~,''%' DATE The space below for Commission use ~ , ~,, % .... · CONDITIONS OF APPROVAL // / Samples required Mud log required Directional Survey require~[~ APl number [-1YES ~NO DYes [~NO ~YES DNO 50- Permit number Approval date ~,"O/. __~2~ 10/05/81 [ SEE COVER LETTER FOR OTHER REQUIREMENTS A,,.ov,o,Y . OMM,SS,O ,. by order of the Commission Form 10401 Submit in triplicate Rev. 7-1-80 PROPOSAL-FOR WELL OPERATIONS Field: Swanso~ River. Property and Well: Soldotna Creek Unit 31-8. Surface Location: Approximately 1,850 feet south and 1,950 feet west from the northeast corner of Section 8, T7N, R9W. SB&M. Bottom Hole Location: Approximately 700' south and 2,150' west from the northeast corner of Section ~, T7N, R9W. Elevation: 128 feet est. G.L. Estimated 145 feet K.B. (oBrinkerhoff #58). Blowout Prevention Considerations: 1. Potential Problems Be Gas and water entries: Gas sands may be encountered at any depth below the shoe of the surface casing. High pressure water sands are known to exist between 6,000 and 10,000 feet. The surrounding wells were drilled with 95-98 pcf mud with no gas or water kicks. Hemlock zone static reservoir pressure is 4400 psi. Well SCU 341-8 is currently injecting gas at 5600 psi. This represents a gradient of .52 psi/ft, or a mud weight of 75 pcf to equalize. Gas and water entries can cause severe hole problems and the mud system should be carefully monitored at all times. Lost Circulation' No losses have been experienced during drilling operations in surrounding wells except for a short period of time at 6,800 feet in SCU 341-8. Lost circulation has occurred in other SRF wells while drilling the Hemlock with 98 pcf mud. In SCU 31-8 casing will be cemented above the Hemlock zone and the mud weight reduced to drill to T.D. Lost circulatiom materials to be kept on hand at all times. Precautions: Any kicks should be handled by normal procedures. Drilling crews should be made aware of these methods prior to spudding. Kick and BOP drills should be practiced at regular intervals and noted on the tour sheets. An adequate supply of weight material should be at the well site at all times. 3. Maximum Anticipated Formation Pressure: 6500 psi in high pressure water sands above 10,000 feet. Maximum Anticipated Surface Pressure: 3800 psi. Blowout Prevention Equipment: Class III 5000 psi and 10-3/4" and 7-5/8" casing. Estimated Depths and Correlations: ~qarker Sub-sea Depth Vertical Depth Drilled D.epth H1 (Top Hemlock) -10,290' 10,431' 10,619' H8 (Target) -10,445' 10,586'~ 10,786' HIO -10,530' 10,671' 10,877' T.D. -10,700' 10,841' 11,058' PROGRAM ' 1. Drive 20" conductor pipe to 80 feet or as deep as possible during rig up. 2. Drill for 10-3/4" casing to 3,400 +__ feet. Maintain drilling fluid per attached drilling fluid program. At 3,400 feet, condition hole for logs. Take ½ gallon sample of mud returns prior to pulling out for log. Run Schlumberger Dual Induction log with SP from effective depth to,shoe of conductor. Use linear scale for 2"/100' track and logorithmic scale for 5"/100' track. Use 10 MV scale for SP and 0-50 ohm-meters for line'ar resistivity scale. Development Geologist to witness. All logs to be taped, o . Cement 10-3/4", 40.5#/feet, K-55 Buttress casing at 3,400 feet. A, Use float shoe and stab-in duplex collar ~Wo joints off bottom. Centralize bottom five joints. Cement through .shoe in one stage with sufficient Class "G" cement pre-mixed with 2.4% gel by weight of water to obtain returns to surface. If cement returns are not received at the surface, do a top job. De NOTE' Class "G" cement with pre-mixed gel at 2.4% by weight of water: Yield - 1.86 cu. ft./ sx. cmt. Water requirements - 1.36 cu.ft./sx.cmt. .Gel requirements - 1.5 lb/cu.ft, of water.. Slurry weight - 98 pcf. Alaska Oil & Oas Cons. Commi,~sior, Have stage collar on location in case lost circulation occu~C~jae drilling top hole. Be Cut off i0-3/4" casing below the top of the cellar (ground level) to allow the top flange of the tubing head to be above ground level after completion. 6. Install 10" - 5000 psi, 10-3/4" SOW .casing head. Test lap weld to 2500 psi. 7, Install Class III, 13-5/8" -5000 psi BOPE as per the attached BOPE design. Test BOPE, kill line, blow line, and manifold to 5000 psi per State Regulation 20 AAC 25.035. Alaska Oil & Gas Conservation Comission and/or U.S.G.S. to witness BOPE tests. . Drill out cement in 10-3/4" casing to within 10 feet of the shoe. Pressure test casing to 2500 psi. If test is OK. drill out shoe. Drill 9-7/8" hole to a t'rue vertical depth of 10,431 feet, estimated 10,619 feet M.D., estimated top of Hemlock sands as follows' A. Follow mud specifications per the attached mud program. B. Take single shot surveys to estimated K.O.P. at a minimum of 480 feet, or at shorter intervals if required. Ce Beginning at approximately 7,000 feet, K.O.P., build 2½°/100' to 20u/ 12 minutes. (Target is top of the H8 sand at -10,445 V.S.S. at a location of 1,150 feet North and 200 feet West of surface location. Along course of North 9o 52' West section is approximately 1,167 feet. 10. At effective depth, con~lition hole for logs. Take ~ gallon sample of mud returns prior to pulling out for log. Run the following Schlumberger logs' A. Dual Induction log with SP and GR from effective depth to shoe of 10-3/4" casing. Use linear scale for 2"/100 feet track and logorithmic scale for 5"/100 feet track. Use 10 MV scale for SP and 0-50 ohm-meters for linear resistivity scale. Use-O-lO0 GR scale. B. BHC - Sonic log - SP from effective depth to_ shoe of 10-3/4" casing. Use 50-150 microsecond transit time scale. C. Have FDC-CNL tool, sidewall sample gun, and TDT tool on location. Shoot S.W.S. as directed by Development Geologist. 11. Drill ahead if indicated by log to set 7-5/8" casing shoe at top of Hemlock H- 1 sand. 12. Run 7-5/8". casing as follows' Bottom: 2,200 feet 33.7/#ft. S-95 LTC Next: 3,320 feet 29.7#/ft. S-95 LTC Next: 1,900 feet 26.4#/ft. S-95 LTC Next: 3,120 feet 26.4#/ft. N-80 Butt Top: 80 feet 33.7#/ft. S-95 LTC NOTE' For deeper casing depth add 33.7#/ft S-95 .LTC on bottom as required. Be Run diffe'rential fill up shoe and collar. CJ D. Run stage collar at approximately 7,500 feet. Centralize bottom 500 feet and above and below stage collar. E. Cement in two stages as follows' (1) Shoe job Use sufficient Class "G" cement treated with 3/4% CFR-2 to reach near 8,500 feet. Mix to slurry weight of 118-122 pcf. (2) Stage collar: Use sufficient Class "G" cement pre-mixed with 2.1% gel, by weight of water, 'to lap into the 10-3/4" casing at 3,400 feet. NOTE' Class "G" cement with pre-mixed gel at 2.1% by weight ~a~ter: rcl 'i V£1 Yield - 1.68 cu.ft/sx.cmt. Water requirements - 1.18 ft. /sx.cmt. JUL 0?]$8 GelslurryrequirementSweight: _- 1.3102 pcf.lbs/ft' water.. ~ask~Oil&QasO°aS. Oom~i~· 13.. Remove BOPE and land 7-5/8" casing. Install a 10" 15000 psi bott~'~'~f~enge x 8" - 5000 psi top flange tubing head. Test secondary pack-off to 5000 psi. Install 13-5/8" - 5000 psi Class III BOPE. Test BOPE, kill line, blow line and manifold to 5000 psi per State Regulation 20 AAC 25.035. Alaska Oil & Gas Conservation Com~mission and/or U.S.G.S.,to witness test. · 14. Drill out stage collar and cement to within 10 feet of 7-5/8" casing shoe. 15. Run Variable Density- CBL-GR log from effective depth to above top ~of cement from stage collar job. 16. Based on CBL, squeeze for WSO above Henilock as required. 17. Pressure test 7-5/8" casing to 3000 psi. · 18. Condition mud weight to 70-72 pcf. 19. Drill ahead' in 6-5/8" open hole to a true vertical depth of 10,841 feet, estimated 11,056 feet M.D. Maintain angle to intercept target at -10,445 VSS at a location 1,150 feet north and 200 feet west of surface location. 20. Condition hole for logs. Take ½ gallon sample of mud returns prior to pulling out for log. Run the following Schlumberger logs. A. Dual Induction log with SP and GR from T.D. to shoe of 7-5/8" casing. Use scales in an intermediate log. B. BHC - Sonic 'log from T.D. to shoe of 7-5/8" casing. C. FDC-CNL SP-GR. Take SWS as directed by Development Geologist. 21. Condition hole for 5½" liner. 22. Cement approximately 640 feet of 5½' 20# N-80 buttress casing at 11,056 feet with sufficient densified (122 pcf) Class "G" cement with 3/4'% CFR-2 to obtain returns above top of liner. A. Use float shoe and float collar one joint above shoe. -B. Allow for 200 feet of special clearance couplings. C. Equip liner With 7-5/8" x 5½" Burns liner hanger grooved for cementing. ! 23. Clean out cement to top of float collar. 24. Run Variable Density CBL-GR-CCL log, Compensated Neutron log and TDT log from effective depth to ~bove top of liner hanger. Scales to be provided by Engineering Representative on location. 25. Pressure test 7-5/8" casing, 5½" x 7-5/8" lap, and 5½" liner to 3000 psi. 26. Obtain WSO below base of H8 sand. 27. Displace 7-5/8" casing and 5½" liner to E.D. with lease crude, ii//_ 0;7 Alaska OiJ & Gas Cor~s. Anchorage 28. Run 3~" completion string with single packer per supplementary program to be issued after logs have been run. 29. Remove BOPE and install x-mas tree. Pressure test tree to 5000 psi. 30. Perforate, through tubing, lowermost single sand indicating low GOR per supplementary program. , 31. Release rig, place well on production as directed. M. J. Allison JUL 0 Oil & ~as COns. C°m~issio~ ~chorage DRILLING FLUID PROGRAH - SCU 31-8 SWANSON RIVER FIELD Basic Dril.l.in~. Fluid System Medium treated lignosulfonate mud. Optimum Drilling Fluid Properties Mud Properties Mud type To 10-3/4" CSG. PT. Recl aimed mud or ex- tended gel From 10-3/4" CSG. CSG.PT. to 6,000' Extended gel From 6,000' to 7-5/8" CSG.PT. ~ignosul fonate From 7-5/8" . CSG.PT. TO T.D. Lignosulfonate Weight - pcf 68-75 70-75 75-100 (2) 70-72 Viscosity - sec/qt. API 45-200 (1) 35-45 43-47 43-47 Fluid loss-cc - - 7-10 4-7 API P1 asti c - 18-24 18-24 18-24 vi scosi ty-cps Yield point - 8-12 6-8 6-8 lb/lOOft. pH - 8.5- 10.5 9-10 9-10 Calcium-ppm - 50 max. 50 max. 50 max. Solids content % vol. - 7-13 13-25 6-10 · Remarks 1.' High viscosity as required for surface drilling. 2. 100 pcf maximum anticipated required mud weight. Raise mud weight to 93 pcf by 7,000 feet. . Have high pressure - high temperature drilling fluid test equipment on, hand after drilling out shoe o'f 7-5/8" casing. Make fluid loss tests at estimated bottom hole temperature of.170 degrees F. JUL 0 ? ~98i AJa$~a OJJ & ~a~ Co~$. Comrnis,~. '. -.~000 ~ · . "i/~"-':o~o~.3 ...... · - 3"xooo~ ~ .. ' 'I/3~"- 7000 *~ .... ~.'--~ .. , ~' . ' ~ ,, ~z ~o /o"-sooo~..~~' o SChEmE0 2"- JUl_ 0 I. I CHECK LIST FOR NEW WELL PERMITS ITEM APPROVE DATE ,, //~3/< ?-F'Y/ thru 8) ie e 3. 4. 5. 6. 7. 8. Company LLo, Lease & Well No. YES NO Is the permit fee attached .......................................... Is well to be located in a defined pool ............................. Is well located proper distance from property line .................. Is well located proper distance from other wells .................... Is sufficient undedicated acreage available in this pool ............ Is well to be deviated and is well bore plat included ............... ffe ted pa ty ' /~ Is operator the only a c r .................................. .... Can permit be approved before ten-day wait .......................... K/ ~ __ REMARKS (3) Admin (9 thru (4) Casg~ [ O/%/~, (12 thru 20) (5> BOPE ~ .,14Z/~( (21 thru 24) (6) Add: 9~ 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. Does operator have a 5ond in force .................................. /~o~ Is a conservation order needed ...................................... ~4oK Is administrative approval needed ................................... ~.~ a~ Is conductor string provided ........................................ Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings -..d~ Will cement cover all known prodUCtive horizons ..................... Will surface casing protect fresh water zones ....................... __ Will all casing give adequate safety in collapse, tension and burst..~.,.' Is this well to be kicked off from an existing wellbore ............. Is old wellb°re abandonment Procedure included on 10-403 ............ Is adequate well bore separation proposed ........................... __ Is a diverter system required ....................................... Are necessary diagrams of diverter and BOP equipment attachedP g ~k ''''''' ~~" ' Does BOPE have sufficient pressure rating'- Test to .C~oo si . Does the choke manifold comply w/AP1 RP-53 (Feb.78) .................. --___ /Vm~ fo[I;~/~ Additional requirements ............................................. ~ Additional Remarks: ~[~ ~¢~ ~(~e~ ~ ~'{ ~~ ~~ ~el~ ~0r~ ~[~+. /~~ ~ ~~Ve~~' Geology: Eng~ring: . z "nCS/ EW · rev: 03/10/81 INITIAL I GEO. UNIT ON/OFF POOL CLASS STATUSl AREA NO. SHORE CHECK LIST FOR NEW WELL PERMITS Company Lease & Well No. ITEM APPROVE DATE (1) Fee (~ thru 8) 1. Is. the permit fee attached ........................ ...... ....... 2 Is well to be located in a defined pool ......... ..'1. 3~ Is well located proper distance from property line ii, ii i~!!![i[i]i 4. Is well located proper distance from other wells '. 5. Is sufficient undedicated acreage available in this 6. Is well to be deviated and is well bOre plat included .......... 7. Is operator the only affected party ............................ 8. Can permit be approved before ten-day wait ..................... (3) Admin ~_~ ~~ 9. ~~9 thru 11) 10. 11. (4) Casg ~~thr ~'~J~ u~20) --~1 £hru 24) (5) BOPE 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. (6) Add: ~~ YES NO · Does operator have a bond in force .................................. Is a conservation °rder needed ................................. ..... Is administrative approval needed ................................... Is conductor string provided ........................................ Is enough cement used to .circulate on conductor and surface . Will cement tie.in surface and intermediate or production strings' W±ll cement cover ail knOwn productive horizons ............. Will surface casing protect fresh water zones ..................... Will all casing give adequate safety in collapse, tension and burst Is this well to be kicked off from an existing wellbore ........... Is old wellbore abandonment procedure included on 10-/403 .......... Is adequate well bore separation proposed ......................... Is a diverter system required ...... i~g~'a a hed Are necessary diagrams of divert er ~ ~'g~ '~'g ..... Does BOPE have sufficient pressure rating -Test to · Does the choke manifold comply w/API RP-53 (Feb.78) ................ Additional requirements ............................................. REMARKS Additional Remarks: · Geology: Engineering: HWK LCS BEW WVA JK~ rev: 01/13/82 INITIAL - GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE 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, FILE:I_A1360 PR, OGRA~:LISTER CILD PAGE CHEVERON USA INC. SCU 31-8 .... G-RI--'AN-D--CA-L! ...... A-RE"-RO ~J' WITH"'-B'HC' 'A'C ! N' '"THE-"L OW-CR'-'"'SE-C ¥'i'0 N--~'' B'E-L'O'~ ..... i'O-~ 0-'~ ....... ~'T--; ................................................ .................. OEPTH ................. GR ............. GR'I ................ SP ........ CAL ....... C-AL"~ ........... [~E'N ........ DE'NP ............ 'CN- .................... A'C' ........ ~-¢-~'~- ......... '[{'~"~M ....... [¥~-L-[~' ....... ............................ K'T ........... A"P"! .......... AP'i ................... ~V' .......... iN ............ i"~j ....... G-2 C .......... ~ ~ ................. ~5'7"0-'; ................ 28';' ............... 0 '; ............ ~'-~'~'; ................ iO-; 0'~ .......... 0', O0 ................... 0'~ ............... 0-; ........ 75; ...................... O-;iO-O'"~-O-;-I~'ti-O'~-;- ........ .................... 3'~7'I-; ................ 2'~'-; ...................... 0'; .............. ;'35; ............... ~ 0"; ........... 0-; 0-,'-'0'0 ............. 0-; ............. '0-'; .............. 7'~-, ................... O-;-i'O'O'-~'~-';-I'O'-O'~-~' ~ ............. ................... 3'37'3'; ..................... ~'7. 0'; .................. ;39"; i 0-'; .............. 0 ;" 0","'0"0 0'"~ ................ 0"; .......... 7'3"; O'";'-i'-O'O"~-O";"~'"O'"O"~"~'"~ .............. 7' , O. 00~0. O. 1 .00 O. O, 0.10000. l, * O, 0000, I 3, .00 O. ,00 O. ,00 O, O. 10~, O. 115. O. 120. 13. 1.~, 8. 1,3· 15. 8, 1.3· 14. 10. 13. 14. 6. 9, 11, 6. 7. 9, PAGE 2 CHEVERON USA INC. SCU 31-8 ..... G-Ri-'--AN'D---CT~[i-'-Aiq-£----'iiO-~i""-~'i-TH----*~-HC ~-d iN-"- 'T-Hi~-iZ'O'W'-C-R'-'-~-Ce'i'i-O i~' ~'B'£-L6'~ ....... i'6-§'6'6 ""~*'i-;~ -' ............ 6-£P-Y'H': ................... -~-~, ........ ~"--~-~-~ g'P ............ ~:A-[ .......... CX'L'~:F .................. 6-~'N-""~--D'[N'D .................. 'd~ ................... :~e:'~ ........ ~'~'6'fi''~ ......... -~-~-~N: ........ ~'"~L--D'~'~-'- P'Y ............ A-Pi- .............. A'Pi ................. R-¢' .................. i-N ..................... i"~i ............... '~'2~ '~ '~ 3 3. 8. o. GT. l~+. ' o 2 'd;"6-6 0"; d"; ................... i'b"~-';' ................................. ~'"~ .................................... '~"-; .................................... ~"';' ............ O. 0.00 O. O. 82. 7. 7. O. 0.00 O, O. 100, 6. 6, 7. O. 0.00 O. O, 116. .00 O. O. · 5, 5. 6. O. .00 O. 5. 8. 8. .00 O. O. 106, 8. e 10, ' 1. O. 0,00 O, O, 125, 5. 6, 7, , O. '~ O. 0.00 O. O. 111, 7. 9. 9, , O, -65, 13, O. 0,00 O, O. 111, 5, 6, 7, PAGE :5 O, - .0, 1 O. -51, 13. O. -~ 13, O. 3~ )® 0,00 O. O. 102. 9. 10. 12, 0,00 O. O, 11~, 6. 8, 10, 0,00 O. O. 111, 7. 8. 9, .00 O. O. 1~, 7. 9. 10. ,00 O. O. O, 8, 9. , 7. 10. 11, 3~ O, 8, 0,00 O, O, 105, 8. ,00 O. O. 110, 8. 9, 11, 10, ;0~ 11, 11, 12, 9, 11, 7, O, -50, 15. O. 0,00 O. O, 110, 6. 9, 11. 25 O, PAGE CHEVERON USA INC. SCU ~-8 ........... FT AP1 API MV IN I~ G/C 3 9. ,6. O. -51. 1~+o 0. 13. O. 0.00 O. O, 0.00 O. O. .00 O. O. 98. 5. 6. 7. 11~. 6. 7. 8. 110, 7. 9, 10, 8, 10, L2. , 8. 10. 12. , 7. 11' 13. 3 . O, o 1 , O. 6e 8e 10. 7. .00 O. 11 G. 9. 8. .00 O. O. 10~. 9. 1.3. 1~. 0.00 O. O. 96, 11. 22. 22. . O. -~2. 13. O. 0.00 O. O. 90. i~. 17. 21. 3561. PAGE 5 :3 1i, O, · 5~ 1 O. 0,00 O, O, 113, 5, 0,00 O, O, 115, 5, .00 O. O, 110. 6, ,00 6e 7e 7. 7. . . O. . 6. .00 O. O. 12 6. o00 O, O0 O. ,00 , 7. O. 119. 6. O. 11 7. O. 10 . 8, . . t . 9. 11. . . . . . 10. 12. 3 '0, O. '~8. 13. ~ 5. · I 0.00 O. O. 97. 10. P2. 23. .00 O. O. . 60. 31. 0.00 O. O. 82. 12. 18. 23, 0.00 O. O. 90. 12. 15. 16. 11. 1.7. PAGE CHEVERON USA INC. SCU 31-8 FT API ....... A'D'-~ ................. MV ............ i"N ................. ~h .............. G"2~ 1. o. o. .... 0";'6'6 3t · O, ¸34 O, '5, O. '46, 1 O. 0,00 O. O. 96, 10. 1~, 21, '51, 13, O. 0.00 O, O, 102, 8, 9, 12, '5~, lq, O. O.OO O, O. 116, 6, 7, 1~, 0,00 O. O, 110, 6. 6, , 1 . O. 0,00 O. O. 10~, 5. 5. 6. 5. Go G, 6, 6, 7, 5~ 11 12 -45. 15. O. 0.00 O. O. 105. 8. 12, 15, O, O, O, O, 1~, O. 0.00 O. O. 99. 10, 15, 18, -~0, 1~, O. 0,00 O. O. 99, 11, 15, 18, -~1, 1~, O. 0,00 O. O, 101, 10, 1.5, 18, -40, 1 , O. 0.00 O. O, 105, 10. 14. 17, O. 0,00 O. O. 112, PAGE ? CHEVERON USA INC. SCU 0o00 O, O, 0.00 Oo Oo 104. 9. 1~. 104, 10. 15. · 11. 16. !1. O, 1( Oo 1~. O. O. -~ 1~. O. O® O · .00 O. O. .00 Oo O. .00 O, O. 0,00 O, O. 0,00 O. Oo .00 O. O. 0,00 O. Oo 0.00 O. O. .00 O. Oo 6. 7. 8. 6. 7. 9. 107. 7. 10, 11, 100. 9, 1.3. 10. 15. 17, 10~, 8. 11, 1~. 10~, 8. 13, 16, 86, 15. 19. 2~. 86. 15. ~, ~1. 85. 15. 18. 25. 10, 1~, 20. PAGE 8 CHEVERON USA INC. SCU 31-8 ....... ~-~--i' '-'~N~-"--C-A' L'i ...... A-~--£-"'-~-O'~'--'-~' i-TH' "~"H-~-" '- A- '~ ..... i -N'-'""¥'H'~'-'"L 6-~"~"~'-'-~ ~'~-i-'i-~ "~-: 'B' E -C ~'~ ...... i'O' -5 6'0 "--'-~ ¥"~ ........................................ "__-.'_iii ~_i. i ii~?'! H'~'i':ii i'iii i ii'~'i~'.iR-_-_i.i i' i. i iii-~i~Rii'i.~.i'2'.i i'Zi,~ '.~i ~'ii'i '.'i'ii-i i'C~ii ~i 121 'C~.c~'i'.' T-i.i'i i,~i.~.'~ iii i ',-'i~_'.~i~'ii ii iiii.. Ti~'c_'i.~i-_iZ ii i ii'ii i'i-i~-~._-~ii"-.~' ~-_~'i'O_"_6_'Z'2~'i~_L-_~_-2_-.~.._L..b__'~_-ii FT AP1 AP1 MV IN IN G/C ~ ~ 3' · 3, O, '~, 15, O. 0,00 O. O. 85. 17. P4. ~2, 7. O. -47. 15. O. 0.00 O. O. 95. 8. 12. 19, . O. 0.00 O. O. 10: . 10. 1.2. 18. 1 0,00 O. O. 10~, 9, 9, 130, 6. 6, 8, 5. 5, 5. 5. 6. T. ?. 9. .00 O. O, 11 , 7. 9. 15, .00 O. O. 11,. ?. 9. 1~. 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P~. 21. ~2. 80, 16. 19, 33, 79, 16, ~1. 17. 8. 12. PAGE 14 ~ :7,. 37, 16, O. 0o00 O, 27. 76, 25, ~8, 51, 16, O. 0,00 O. 28, 76, 25, 29, 5~, 16, O. 0,00 O. 30. 77. 25. ~9. 52, ,00 , 25, ~9. 55. 1~, ,00 O. O, 7~, 25, ~, 13, 18, 30, 21, ~i20, ~5, 51. ,00 O, 9, 7~, 26° ~, ~, O. 0,00 O. O, 8~, 19, 1{, ,00 O, 7~ , 23, 2~, ~0, 1~, 0,00 O, 31, 81, 20, ~2, 37, 15, O. 0.00 O, 30, 81, 18, ~3, 37, O. 0,00 O, 30. 7' , 22, '~8. 16. O. 0,00 O. 27. 77. 24. ~0. 55. ,00 O, 32. P8, 50, '; ...................... ;"~'7";' '0'"~" ,00 O. 8~, 18, ~$, ~0, 8~, 20, ~2. 56, PAGE 15 CHEVERON USA INC. SCU 51-8 ......... G~-'I'"-'-'A'r~D '"UAL'I'-""ARE'-"R'O~'-'" WI'TH'-'-BH'C-" A'~- -IN-' '"THE"-~"O-W'ER'--'"S'E'C-T ~-O'~"-."BE"E'O-W'"' i "0--5-~-"~-"~-¥ ~ ................................................ .... ~ ............ OEPTH ................... GR ............. GRI': ............... $'P ~'A-L- ...... ~'A'[-~- .............. D-E'N ......... 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G, 7. ~ · 7'° 5,, ,5,, 0 1t 10. 8. 5 · 0,00 O. 55. 95. ~. .00 O. lO0. l~. 0,00 O. ~G. 97. 7. .00 O. ~G. 117. 5. e 9. G. 5. !0. 12. 8, PAGE 5; 1 , O. 0,00 O. 5; 1 ,00 O. ~, 108, 6, 6, 7, ~5, ill, 5, 6, 7, · 6, 7, 8, 6~ , 6, 6. 7. , 8, 7, 8, G. i .00 ~ · .00 O. ~7. 12 , 17. 10. lq., 0"'; ............................. ~"5";' 2 0 , 6. 8 , 10 , · 8, 7, 8, 7. 6. 8, 5. 6. PAGE 40 CHEVERON USA INC, SCU )1-8 FT API AP1 ~V IN IN G/C :~:::"':'-'~'5"2~::;"-'"'~"~:;:": ......... :'"::~":0';' 5: ,.5: -~+( I O. -~8, I O. ¸ 5 · 1; 5 5 1;, 0,00 Oo 0,00 O, ,00 O, ~0, ,00 O. ,00 ,00 ,00 ,00 0o00 O. 0,00 O. 48. O. 5 O. 46. O. 47. O. 47. O. 45. 125. 10. 10. 10. 111. g. 10. 110, 8, g. 11, 9, 11, 2, 98, 11, !~1' 11;, 7, 12, 16, 9. 6. 4. 5, 6, 6, 6. 6, 5 5. 7, 111, 5, 5, 5, 109. 5. 5. 6. 108. 7. 7. 7. 110, 8, 9, 11, 118, 8, 9, 11, 112, 6. 5, 7, 5 , 41. '49. 12, 5 1 · 0.00 o00 ,00 .00 O I 98. 6. 7. 7. · 6. 6o '79. 4. 5. 6. 6, 6. 6, 5. 7, ?, PAGE CHEVERON SCU 31-8 ....... 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G, 0,00 O. 41. 101, 5. 5, 6, .00 O, 108, 5. 5. 5, ', 5. 5, 6. 5 '8, · 5. G, 6, · 5, G. 7, 5. 6, 7, 5. 7, 8. -41. 15. O. .00 O. 0o00 O. .00 O. .00 119. 36. 127, 118, 1 Ii'7, 0 70 80 5. 7, 7, 5. 7, 8, 5, 7, 8, 5, 7, 8. 6. 9. 10. 5. 8. 9, 5. 7. 8. 5. 6. 7. 5, 6. 7. 5. G. 7, PAGE 45 CHEVERON USA INC. SCU 31-8 ............... 0,00 O. 9', 1 .00 0 . .00 . 80, i8, 12~. 5, 9· 8, 15. ~2. 11, . ?e . 5, G. 6, 7' ?e 11 · )0 O · 105. 10 !. ~. 5. 5. 4. 5. 5. ~ · 5. 5 · 4., 5, 5, ~. 5, 6, -41. 16. O. 1t · 1 0.00 O. 39. .00 O. .00 O. 29. .00 105, ~. 5, 6. 118· ~. 6. 6, 9'. ~. 6. 6, 5. 1.0. 8. , 7. 6. 8, PAGE 46 CHEVERON USA INC. SCU 31-8 ...... G-i~-I'"'-'-'AN O--"-¢A'E'I- ......... 5~ 1 O, 5t 51 Oe ,00 O. 27, ~7o 26, 0,00 O, 55, 131, 25, ~0, 33, ,00 O, 49, 131, 12, 1.2, 17, 9. 7. 9. .00 O, · 5, 5, 7, 5, G. 7. 6, 7. G, 7, 8, 6, 7. 8, 7. 8 ,00 O. 6. 10 , 6. 8, 9, .00 O. . 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O~ 0.00 o00 0.00 ,00 ,00 o O, O, O, 55. 37. 97, 0 5~ PAGE CHEVERON USA INC, SCU ~1-8 6 O. 6 '4; 14, 0.00 O. 64. 126. 0.00 O. 57. 122. .00 O. 118. 152. 79. 258, 29. 14· 28, 12, 10. 12. 9, 10, 9. O. 8, 7, 8, .9, )· 6 1!· 6 14, O. .00 O, o00 O, .00 O, 0.00 O, ,00 O. .00 · 00 O, ,00 · 50, 124. 115. 43. 101. 41. 90. 35. 31. 8, !5 26, 1.3, , 22, Pl * 27, 23. 13' 22, 7, 7. 10, 5, 5, 7, 5, 5, 6, 6. 6. 6, 6. 6. 7, 6. 6, 7. 6, 8. 9, 6. 6. 8, PAGE CHEVERON USA INC, SCU 31-8 6 O. 0,00 Oo ~1, 9~, 6 O. 0,00 O, W 95, ', I · .00 5. 6. 6, 0 Q 6e 6e 5. 5. 6, : .00 ,00 O. 125. O. ~5. 10 O. .00o 6® ~. 5. 6, 6. 7. 15. 8, 11, 10. 9, 11, 6. 6. 6. 5. 6, 61 .00 .00 08. 5. 5. 6, 6. 6. 6. 6. 7. 6. 5. 5. 5, PAGE CHEVERON USA INC, SCU 31-8 ......... GN"~-"" ANO--C-'AC1 AR'E--' R-O N' ~'I T-H-B'H-C-' '-A'~ ...... j'N -" tHE'-' ['O-W-E'F~'--'S~'C¥'iON':-B-£-['(J W-- ~ 0"~'~-'0 ..... ~-'T '~ ............... {D-E'P-YH ~-R ............. ~'R'~ 8-'P' ........... ~'~-L- ....... ~'A"[-~ ............ ~'~N ..... 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SCU ~1-8 ......... -G AY--'AN D--'-'C ALI-" ....................... g~'7'3-; ....................... 3~'"; ....................... 9! . 5, 6o 6, · .00 O. O. 9 5. 6. 6, ?e · · ~e · , 39. 1.9, · 7, 11. 14. 1 , .00 O. 42. 98. 4. ~. 5, i'3"; ......................................... 0'"; .................... 0'";"00 ........................................ 0 ~. 5. 5, ~ .00 O. O. 4. 5. 5, · O. ~. 5, 5, · ~o 5. 5, PAGE CHEVERON USA INC. SCU 31-8 ........... 5EPYH .................. ~ ................ ~-~i .................... ~P ............. ~'~'[ .......... e'A-['i ................ 6~'N ......... O'S'ND ............... ~N ..................... ~'~ .......... ~'~6fi .......... ~iE'N ........... ~'i-L6 ...... ................................... ~'Y .............. ~P-i ............... ~-Pi .................... ~'V .......... iN ................... i'N ~-2'~ ................. ~ .................... 52. -38. · -37, 12, O. 12. O. 12, O. 6 · Oe 0,00 O, qT. 97, 0,00 O. 44, 104, 0.00 O. ~2, 100. ,00 O. ,00 O. ~0. 95, ,00 O. ~, 120, 26. 1.0, 18, ,00 O, O, 5. ,00 O, ~0, 85, 6, 6, 7, ,00 O. ~1. 91, 0.00 O. 40. 95. 6. 9. 9. 0.00 O. ~0. 81. 9. 8. 10, 6 il. - 8. 12, O. 0,00 O, ~. 102· ,00 O, ~6, 5, 6, 5, 5, 5, 5, 6, , 5. ?. ?, · 6. , PAGE CHEVERON USA INC, SCU 31-8 ........ GR*I "--' AN D- '"C'A-EI-" 'ARE-"R-0-N--"~ TH~-BH C '-A-C ......... IN--THE-E"or~ E'R--'SE C Y -~-ON'-~'BEE0"W"--1-0-~-0-0'*-'FY; ........................................... ................................. FT .............. AP1 ............. AP1 ..................... RV ................. I N ...................... IN ............... -~"?'~ ...................... ~ ~ 8o 6. 7, 6e · · 5. · · 6e 6. 6, 6, 5. 6. 6, . 5. 6. ,00 O, 10 . 5. ,00 O. ~1. 105' 6. .00 O. i8. 109. 5. 9. 9. 12. · · 0.00 O. 57. 126, 11. 15. 19. .00 O. 12', 27. 25. 51, 0,00 O, q~. 118, 28, 1.1, 18, .00 O. qO. 10 6. 7. 9. · 00 O, 8 , 7, 6, 7, PAGE 70 1;. O. 0.00 O. ~9. 12, O. 0,00 O. ~5. 1 o00 O. 96, 7. 7. 8, 90. 13. 9. 126. 10. 19. ~7. ~8o . 10o 7. 2. 5. 6. 7. ~o ~o 5. . . 5. 5, 5. . 9: . 5. 5 · 90. 9 o Oe 5. 5, 5. 6. ~, 5, 5, . .00 O. PAGE 71 CHEVERON USA INC, SCU 51-8 ........ G R-I--AND-'-CAEI'-A-RE-"'RO'~ WI-TH'-"BH C- .............. DEPTH GE .............. GR! ................. S-P .............. ~AL ..... :'~A[~'i .......... DEN F-T ............ ~PI .............. APl ................ MV '::- ............. g87'0-; ............... 39:; ..................... ~'5'"'; ............. ............... '~-87I'; ........... $6-; ................... '~'7"; ::: .................... ~'872-;-"": .......... :'"'~'3':;::'"': ............. ~"8;'; ......... ......................... g87'3; ....................... 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'q;"8';' ............................. 54-; .................. ';:"$'6'"; ............................ i"P'"'; ..................................... , $. 3. 3, o 8. · .00 ,00 · O0 ,00 ,00 6. 6, 7, 7, 6. 6. 7, O. i6, 9., 6. 6, 7, O, 36, 106, 5, 6, 6, O. 36. 101, 5, 6, 6, { 6~ .1, 13. 1 0.00 O. ~*, 92. 6. 7, 8. O0 O. 6. 9, 10. .00 O. 119. 10. !0. 11. .00 O. ~: 10. 5. 6, 8, 6. 5, 6, PAGE CHEVERON USA INC. SCU 31-8 ...... G-R-I'--AND'"--C-A'E-I---'A-~£"--R-O-~--"-'W-'IT~"-"-BHC"'"A-C'" 'i"N" "-~H'£--' LO'W-~"R'-"-~'E-C-Ti-O'N'":'8'~-[-~'~ .... i"0-5-0'"~'--"F-¥'-~ ..................................................... ............... ~'EP'T'H': ................. :'"'~R- ........... -~-~-i ...................... ~'P ............. ~-A'[ ....... -~L"~ ............ O:~'~' ............. ~'£'NP .................. :~'N' .................... :A'~- ...... ~'~'6-~': .......... '~-f'EH- ......... ~-i~-D- ......... ................................ P'-t- ............... A'P-! ................ 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O. .00 O. 101. ~. 5. 5, 0.00 O. 28. 91, ~. 5. 5. O. 0.00 O. 28. 89. ~. 5. 6. Oo 0,00 O, 36, 86, ~o 6, 7, O. 0.00 O. ~, 10~, 5, 6. 7, 7 , 59, I2. Oo 0.00 O. 37. 96. ~. ~. 5. .00 O. 1, , ~. ~, 5, ,00 Oo 9. 9~. ~. 5. .00 O. 7. 81. ~. 5. 6, , ~. 6. 6, PAGE 75 CHEVERON SCU 31-8 ................ O~TH ......................... FT ................... ?07 .... : ................... ?OT'2-; .................... ........................... '7073'"; · 7, 8~ 10. O. 1 ! · ,00 .00 ,00 ,00 · Oe 38. 36. . 5. o 85. 91. 713. . G. 6. 5. 5. ~. 5, 6. 5. 5. 6. 5. ?. 8. PAGE 76 CHEVERON USA INC, SCU 31-8 7125. 48. 40. '33. 14. O. 0.00 O. 20. 71; 6. 34. '34. 12. O. 0.00 O. 12. 71; 4, 36. -34. 12. O, 0,00 O. 16, 7 G. 1 · 0.00 O. 34. 7~ 78. G. 13. 10. 72. 22. P3. 19. 74. 13. 9. 11. 84. 4. 5. 6. . 4. 5. 5. 9:. 4. 5. 5. 9. 5. 6. 6, I ,00 O. '6. 11, 7. 8. , 5. 5, 5, 8, 5, 6. B , 5, 6. ~. 4,, 5. . 5. 6. 86, 5, 6, 7, 7: . .00 O. 36. 88, 5. 7. 7. 5. G, 7. 5. 6. 6. · 5, 6, 6. PAGE 77 CHEVERON USA INC, SCU 51-8 ................................ F-T ................ API ............... A'P-I MV IN I"N ............ G'2-'~ ~ · .00 · $7, 3; o00 20, 12, 18. 8~ * 1; S. 7. 7. 5. 6. 7o · 5, 6. 7. :6. ~ . 5. 7. 7. .00 O. 87, §, 7, 0.00 O. 29. 9~. 5o S. 7. ,00 Oo 28. 79. 5, 8. 8. -'~0o 12. 12. O~ 0,00 O, 26, 102. 5, S, 7, 0,00 O. 29, 102, 5, 6o 6, 0o00 O. 29. 95, 5, 6, 0,00 O, 26. 98, 5, S, 6, 5. 7, 7, PAGE CHEVERON USA INC, SCU 31-8 ......... 'G R-i---A'N'O""--CA'~-i'-'--' A-R-E~"-~-O ~-'' '~' IT'R-""'~ -~-C---'-A-~"" '-Z-N-'-¥H'~'--" 'L'-O-W-~'R '--'-~"~-~T"i-O'N"", B-£-L- ~'W ..... i'-(~-~ '~j ~'-"-~-¥-; ............ ~'EP'YH .................... ~-i~ ................ '~'~i BP ............ ~-A-L ............ C-AL'~ .............. ~'~'~i .......... O-£-N'~ ................... '~-~ .................... 'A-~ ........ :"R-~"6'~' ....... '~'~-C-i~': ......... ~-i'LD .... PT ................ A-P-'~ ............. A'P"i .............. 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G-~"~:"'--A-ND--CA-E-1'-'-A-R E---R' 0 'N-'-'-W' I TH'-' B- H -C '"'--A-'~ ....... ! N-Y HE"--L-O ~"~R--'"~' ~ -C- ¥ i "ON': '~"E-L-O-W ........ i"05- ~--"~-Y-; ............... ?"32-'I-; .................. ~'2'; .................... ~I'; .............. ;"3'~"; ....................... i"3'"; ......................... 0" ............ -0';-0"0 ...................... '0; .................. 5'-I"; ..................... 7'~'; .................. 5-~ ..................... ~-; ................... '~-; 7 · 1 7' O. 0.00 O. 76. 7, 7. 8, ,00 O, * 5, 6, o00 O. , 6. 15. lO, o00 O, · 20. 9, , 1~, 1.~ , 26. ~1. ', 1_7, 7 , ! , O. .00 O. 6, .00 O. 0.00 O. 3~. 90. 0.00 O. $1. 8, 7. 8. 8. 7. 8. 8, 7. 7. 8. , , , 9, 7 il. '~1, 13, O. 0.00 .00 .00 O. ~7. 90. 9 9 ¸, 5. 5, 5, 5. ', 6. PAGE .00 O. ~9. 8{ , 8. 10, '7~· '7,, 6. · :)e · . 7 1:. 0.00 0.00 O. 41. 90. 0.00 O. ~0. 0. 57. 93. 5. 7'. .8, 8~ 8. 7o 8. · 6® . ~; 7. 6. 7o 9. ?, 8. ~, 5. 6. 5. 5o 5. 5, ~. ~. 5, 5. 5. 5, . ,, ' 7. 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'~'; -~-; ?'; ....... 0.00 O. · 1,. .00 O. 7 . 0.00 O. ~ II .00 41. 96. 6. 6. 7. 9 . 6. 7, 8, 00. 6. 7' 8, 9 . 6. 6. 7, )I · o 6. ® ° 76, 100, ° ° 6e I 6. 7, 7. 7, 7, 7, 6. 7, 7 O. · 1: ° 0.00 O. ~5, 92, 6. 7. .00 O. , · 5, 6. .00 O. ~. 89. 5. 6. ,00 O. ~ , 87. 5, 6. ° 6° 7, 6° ?° PAGE CHEVERON USA INC. SCU 31-8 ........ ~R-'I ~ ~ND-"-C-A'Ci"-"A'-R-£-'-'-RO ~~'~''~-ITH -~'~H'C-' ~A-C" ~N-"'-YH-~'~ '~-O-W~'R"-~S~-Y-~-ON'~B'£-L-~'-~'O-~-b-6~-"~Y'~ .............................................. FT API API MV IN IN G/C ~ ~ 7~ , ~?o 7 , 4'6. 1 O. 0,00 O, ~2, 14, O. 0,00 O. 39, 1!, O. 0.00 O, 92. 5. 7, ?, 92. 5. 7, 7, 93. 6. 7, . 6. 7. ?. . .00 O. 45, , .00 O, 48, G, G, ?, 9 8:. G. 7, 7, 87. 7. 8. · 7, 7, 8, O~ ,00 O, ,00 O, 4.0o 8 , G. ?, 8, , ?, 8, · G, G, 8, 5. 8, 8, PAGE 85 CHEVERON USA INC. SCU ~1-8 .............. 757I-; ............... 50; ~'5'-; ........... ;-33'; i5"; ..................... 0"; 0 ';-'0'0 .................. 0'"; ~' 3'; 9'8'"; ~"; ................... '{~'"; ................... i'i"; . 1( . .00 O. *~. 7. ,00 O. ~ 7o 1: · , 9,' , 8e 9e ~e ,, , :3,, , · 7. , 9. 11, 88, 8,, O, 12. . o00 9! 7{ 3 .00 O. 96. .00 O. 39, 90. 6. 7. 7. .00 O. . 99. 5. 6, 6, 6, 7. 7, 6. 7, 7. 5. 6. 6. 6. 6. 5. 6. 6. 5. 5, 5, 5. &, 6. 6. G. 8. PAGE 86 7i 1 .00 O. ,8. 9; . ~. 5. 6. 7, 1;. .00 6. 7. 7. . 5. 8. 9, 5 9~ 10 . 8:, 5. 7, · . 8:, 6. 8. 6. 7, 9, .00 40. 108. 5, 6. 7. .00 O. V 01, 6. 7. 7. 7 , I1, .00 O, '52. 11;. 9. 12, 11. , 11, 10. 13, 7, · 7. 6. 7, . 6. G, 7, PAGE 87 CHEVERON USA INC, SCU 31-8 .............. 7-6~-; ............ 59-; .................. 50'; ................. ;3I'; ................ 1'3"; ............ 0"; ............... 0-;"00 .................. 0"; 3'9'; ............... 9-6'; g; ......................... ~'"; ............................ Y'; 5 ............... 7'672:;'-:': .......... :5:8:';.:':,'::":.~'6:';', ........... ;29"; .................... ~'3';; :"0:'; :': ......... 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PAGE CHEVERON USA INC, $CU 31-8 ............... YTTI'~ ................... ~0'-~ ................... 2?; ............ ~"36; ............. ~-2'; ...................... 0'-', ........... b;"Ob .................... b'"; ................. 20';' ................... ~'?'; ............... ~"~"; ..................... ~"'~'; .................... i"~"; ':, ................. Y'7'T'~-; ................. :30; .................... 2'Y~' .............. ;3~'"; ........................ -~"~'; ............................ ~'"'; ............. b";-b'b ......................... b'"';' ..................... '~-~"; ....................... ~'4--; ........................... ¥; ........................ T'-; .................... ~'6'-,- · I · ,00 O. 9~ , 5, 6, 6, 9'7. ~. 6, 6. ~, 6, 6, , 8¸0 e , 5. , 6, · 5. 6. 6, 19, O. 0.00 O. ~3. 96, 5. 6. 7, , ,00 O. 6. 6. 6, , O. 0.00 O. 38. 85. 6. &. · 5. 5, PAGE gO CHEVERON USA INC, SCU 31-8 7~ · 1~, O, 0,00 O, 35, 89, 5. 5, 5, 1~, O, 0,00 O, 32, · 1 · ,00 O, O, 88, 7, 9, 8, · 6. . 8. 5, 6, 7, 5, 6. 6, 5. 1 , ,00 O. , 11, 8, ,0, 5. 6. 7. 9; . 6. 6. 6, 5. 6, i6, 1~. O. 0,00 O, q5, 103, 7. 5. ,00 ..... 0"; .............................. ~"5. , 6. 6. 5, ,00 O. ~ 86, 7. ?. 8, .00 8, 7- 8, PAGE 91 CHEVERON USA INC, SCU $1-8 ............. 7'87'I'; .............. 52; .................. 5'3-; ............. ;36"; i'~"; .............. 0'; ............. 0'";"0-'0 0-"; ~-0-; '~-?-; ................. ~'-; .................. ~-; .............. ~-'; ...... 1', 0,00 O, 7 , ! 0,00 O, O. 11;, 7. 7. 7, ~7. 113, 9. 9. 9, ~ 8. 8o 9. , 8, 7. 7 · · I , ,00 ,00 O, ~ , , ,00 ,00 O. 37, 81, 0,00 O. g~. 93, .00 O, 7~ 6, 6, 6, 6, 7, 7, 8. 7, 8. 6, 7, 8. 6, 7. e 7. 6, 6, 6. 7, ?e 6, 5, 5, PAGE CHEVERON USA INC, SCU 31-8 7 lq* 0,00 O, 7 , ,00 O, ,00 36, 91, ~, q, 5, 89, 5, 7, 7 , 8, 7, 8. , 6, 7, 7, 9; 5, 6, 5, 6, 1; o00 11, .00 O, , ,00 O, 19. 75, 108, 5, 6. 5. 5. 5. 5. 5. 5. 5. 8. 13. 18. 13, 56. ~. 37. ~2. 52, ,00 O, ; ................................ i"2'; ......................................... 0"; ...................... 0'"';"0'0 ........................................ , 115. 9. 9. 5. 5. PAGE CHEVERON USA INC. SCU 31-8 , 9~, 5. 5, 5, o00 iT, 91, §, 5, 5, · 5, 6, ° 5, · 6. 7, 5e 5, 6. 6. 7. 8. · 6. 7. 1 ° °00 O. ZOO, 7, 8. 9, ;00 5. 6. 7, 5. 6, 6, ,, , 5. 6. 6, PAGE CHEVERON USA INC, SCU 31-8 FY API API MV IN IN G/C ~ 8 6, 6, 1 , O. 0,00 O, ~, 87, 5, 6 ~5, 12, O, 0,00 O, ~8, 97, 5, 6, 7, 8 1;, O. 0,00 O. ~7. 117. 6. 6, 6, 3. 3. 81 8 ~. 5. 6, 8 q~. q'. 5. 8 8 8 O. 8 13. , 8t. 3. 2. 2, ,00 . 105, 2. 2. 2, .00 O, 37, 90, 3. 2, 2, ,00 O. 35, 90, 3. 3. 3. .00 O. 35. 89, 3. 3, 3, 0,00 O. 33. 88, 3. 4. ~. 0.00 O. 37, 88, 3. 3. ~. ,00 O. 36. 90, 3, 2. 5. 2. 2. 2, 3, 3. 3, PAGE 95 CHEVERON USA [NCo SCU 31-8 ........ GR1--A ND-'-'CA-EI'-'-'ARE--'RON-.-~r~ TH' '---'BHC"--AC" 'IN'-" 'THE"'"'E-O'WE R-'--'S EC 'T~-ON-iBE -L' OW- -I-'0-5' 0" O'"-"FT-; .................................................. -: ............ 'DEPTH''-'~ ................ GR'"-; .......... 6RI ................ :"SP-"-'; ........... 'CAE- ......... CA-L;i DEN ........D'ENP ..................... 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L20o 1 5. 5. 5, ~. 5. 5, 5. 9. 9. 32. 1.3. 15. 8. ?, 5. 5. 6. 5. 5. E,, ~. 5. 5. PAGE 96 CHEVERON USA INC, SCU ~1-8 ............ G~"i--A-NO-~ CA~'~-'A"~{-E-'--~-0 N~'''''01~'-T''~ "~8~H-C"'- - A'~ ~'~N-'¥HE 'E0'W-~'~ "~"~'E'~~Ti' O'N':-B-E~L-0 W ...... i 0'~' 0-0~''' '~' 8 3.3. O. 8 · 1 0o00 O. 39. 96, 5, 5. 0,00 O, 37, 91. 5. ~, 5. ,00 O. 36. 88, 84, o00 .00 0.00 .00 ~. 5. 5. ~. 6. 6, 6~ O. 20. 62, 0 ~ 9. 10. 13, g. 6. ?, ~o 8. 5. 6, 7. PAGE CHEVERON SCU 51-8 ............. :: ................ DEPTH ,- .......... ................... .................... 'B'IT'~"'; · 00 0. 5. ~. ~. ~. .00 0. 18, 8o 7. · 6. 'e ~e 5e 8 8 1 O. 8 13. 0. O. 9. 1. 6. 5. 7, 5. 5. .00 O. 95. 5. 5. .00 O. 5. 5. .00 O. 56. 91. 5. 0.00 O. Sq. 91. 5. 0.00 O. 32. 9~, 5. 8 · 1 0. 0.00 O. 7 , .0O 7. 7. 8. 9. 15. 10. PAGE CHEVERON USA INC, SCU ~1-8 ..... 'Gi~-I--A'ND-'-CA-12I--A-R-E'-~ --R-0'N---W'ITH'~--B -H C--" A-'~ ..... ~N-'--Y HF' i2-0 -W' E'R ~--'-~ -£'¢'Y'~'ON"'~ ElF_ l.-0'~ '-i0"~ 6' 6'- "i~'Y~ ,00 O, q .00 O. ~2. 101, 8. 7, 8, 93. 6, 5. · 5, 5. 5. 8 .00 ,00 ,00 .00 O, 51, O. q5. , 9. o 5o 5, 116, 9, 9, 107. 7, 6, 7, 90, . ~. 3. 3, ~. 5. 3. PAGE 99 1; · ,00 O, 1; , ,00 O, 36. 6. 7. 6. 7e Se 8. 7, 0,00 O, $0, ,00 O, 27, 86. 8.. 10. 13. 8. 11. Se 12. 13. 7. PAGE 100 , 8 o00 O. 0,00 O. .00 O. . O. 0.00 O. I . 0.00 O. 14. 0.00 O. , O. 0.00 O. 4. 3. 6, 6, 7, 6. 6. 6, 7. 5. 5, 5. 5, 6. 7. 8. 8, 54, 12~, 11, 15, 16, 58. 133. 22. ~5. 39. 57. 135. 18. ~6. 35. ~5. 12~. 8. 8. 37. 93. 5. 6. 7. 15. O. 0.00 O. 37. 92, 5. 5. 6. ,00 O, ,00 0 35. 96, 5. 5. 5, 85, ~, ~. 5, , 4o 5, PAGE 101 CHEVERON USA INC. SCU 3~-8 ~-'T ~A-P-'~ ~'P-i' M'~~ ................ ~'N i"'N g'2C .............. ~ T"~ ......... ~ ........................ ~'~73"; ..................... 5I"; 5'3'"; ........... ~'37"; ............. i5'; 0'"; ............... O";"Ob 0'; ................... 3?"; ..................... b'9'; ~'"; ~"';' ............................... ~"; ~e 8 . 7 5. 10. 9. .00 O. 18. 76. .00 O. 56. 9~, ,00 O, jO'"O ...................................... 0 5. 5. 5, 3. 3. ~, 3. 3. 3, 3. 3. 3, PA~E 102 CHEVERON USA INC. SCU 31-8 ........ G-R i" A'Ni:J--CAL'~"--'-Ai~E:--i~'0'i~' FT API AP1 ~V IN IN G/C 8 9, -;;~, 1~, O. 0.00 O, 39, 93, ~, 5, 5, 8 7, -3~, I~, O. 0.00 O. ~3, 107, 6. 6. 6, 8 1~, O. 0,00 O, ~2, 98, 5, 8~ ,00 O, 95, 5, 5. 5, 8' ,00 O, ~ · ~, 5, 5, 8' 9:, ~, 5, 5, 8 7, 5. 8 ~, 5, 5e 8' ,00 O, 92 , ~, 5, ~, 8' O, 0.00 O, q5, 95, 2. 2. 2, 8 I. · .00 O. 37, 97, 3, 2, 8 ] .00 O. PA~E CHEVERON USA INC. SCU 31-8 .......... G~-I'-AND'"CA~'I"- -A'RE ............................. FT ............. API ................... 8'~7'~-; ............. 5q'; ':: ....................... ~'7'2'; ................... 5'0';-' ................. 8'~7'3'; ................... 50'; ....................... ;7T::,~.8~?~;-~ ............ ........................:: , 3. 3o .00 5. 8. 7. 22, 18. 24. 12~. 22. 9. 12. 1 *. 6. 6, 1 .00 O. 17. 88. 5. 4. 4. I 0.00 O. 37. 89. 8 O, -29, 12, O. 0.00 O. 36. 90. ~. %e 0 q. :~. 4-, PAGE 104 CHEVERON USA INC, SCU 31-8 ........ G~"~"-"~'N~--~-AC ~'" -A-RE-~0'~"-'- ~'~T~-'~ ~"'- ~ ....... ~'i~-" YH'~'""L'6-~E ~ '-'~S-~'~'¥'~ 6'~-~'E6'~''- '~'6~' ~'0 FT API API MU IN IN G/C % ................... ~'52'~"; ..................... 53-; ................... 5'3'; ........... ~"'~"; ............. ~"2"; ........................ ~"~ ......... ~'-T'~-6 .................. ~": ................. 3~"; ................ 9"1'; ~"~ ............................ 5'~ 8 O, '4 l;, O. 0o00 O, 38. 95, 8 '44. 12. O. 0.00 O. 38. 94. 8 .00 0. 35. 88. 4, 5, 5, ,00 O. , 4. 7. 6. ,00 68, 9, 6, 4. 5. 5, 4. 5. 5, 8 5, 5, 5, 5. 5. 5. PAGE 105 CHEVERON USA INC. SCU 31-8 ................... 8'57I; .............. 5I"; 1~, ,00 O. 9;. 8 1 O. 0.00 O. 26, 89. 6. 5, 5, 1 80, 5, 9, 7. 6, 5. N., 5, ~, 3, 3, 1; , ,00 O. ;9, ,00 O, 63, 106, '00 O, ~0, 109, 1;, 0,00 O, ~ i15, 0'"~ ...................... O.O0 'O'"~ ............................... o00 O, 14, PA~E CHEVERON USA INC. SCU ~1-8 ......... Gj~"I-'" A'N D" CA'ili ~-'-A-RE--R [iN--"-~I'T'H '*-B-Fi C-'- A C~ Z' N'-'* "t'Fl'l~--[0 -~ i~R'--~"~' ~Z' -C-¥ iON-:-{~-E .00 O. 7to 4. 4. 8t 1 .00 O. 29, 7 4. ~, 4. 8~ ! 0 O. 8 3. 3. 3, 3. 3. 3, 3. 3. 91. 4. 5. 5. .00 O. o00 O. 9 1 ,00 O. 31. 91. 1;, 9 5, 6, 6, 4. 5, PASE lOT CHEVERON USA INC. SCU 31-8 711--i ...... :~-~7"0-'"; .......... -"--'5-5-;,: ........... '5-6-:j'-":'""'~'3'~-'~ ................ ............ 7 ....... 0";i: ...... .......................... 0'";"'i' .......... ii-'-~'?'i~"-': ........ i-~1'9-; .................... ¥"~";-"--7~7~-~,,,,~i~i-' ........................ ~'6~7I'; ................... 52; ....................... 5"6; ............... ;"$"5"; i'2"; 0'~ ........ -0';'-(~'0 0'"'~ ................. 3-7"'~' ............ '~"9'"~' .......................... ~"~ ........................... ~'";' .......................... $'~;- .......................... '~'6'?'3'"; ............................ ~?"'; ................... "57'-'; ............... ;'3'5"'; ........................ i'"2"; 0'; ............ O"';"'~"'b b"; ~"~', ~"~'"; ~'"; ~"; '~"'~' ........... 3. 3. ~, 3. 3. 3. 3. 3. 8 3o 4. 3, 3. 3. 3. 3. 3, , 4., 5, ~- 3. ~. 4+° 1 .00 O. 33. 94. 3. ~. ~. 0,00 O. 31, 87. 4, ~, ~, PAGE 1 OB .00 O. 9 4. ~+. 5. 8 1 .00 O. 9 4. ~. · 5· 8 9', 2, 2, 3. · 8 3. 3, 2, 8 3. 5, 8 3 5. 3. 8 · .00 O. 58. 95. 3. 5. .00 O. 8, 91. ~. 5, .00 O, 19, 105· 6, 5, 0.00 O. 3~. 93. 5. 5. 0,00 O. 35. 87. 5. 5, 0.00 O. 37. 105. 5. 5. 1; , 1 8 1; · 8 6. 1; . · 12. O. 12. O, · 5, 5. 5. 5, .00 O. 32. 89, .00 O. 90, 3. 3, 3, 3. 3. PASE 10~ .00 O. 96. ~. ~. 5. I $ ,00 O, .00 O. .00 O. · 1 .00 O. '0. 90. Bt, ~. 3, 3. 90, 3, 3, 3, 88. 3. 3. 3. 3. 5. 3. 3. 3. 3. 3. 2. 2. 3. 2. 2. 3. 2. 2. ~. 3. PAGE 110 CHEVERON USA INC. SCU ........ ~-R"I-"--/i.-N-O'~ -"C-A-i2-i'"'- A'~E-" "-'i~'-0 FT API AP1 MV IN IN G/C B, ,0. -59. 12. O. 0.00 O. 38. 92. ~. ~. ~. 8. , 51, -58, 12. O, 0,00 O, ~9. 96, 3. ~. ~. 8 8. 1;, 0.00 O, 50. 115, 7. 8. ?. 8 . .00 O. 8. 5. 7o 8; .00 O. 9~. ~. ~. ~. G. 5. , 1; . .00 O. 00. 4. ~. ~. .00 B,}. ~. 4o ~. .00 O. 91. ~. ~. ~. o00 O. 9. 11 . ~. ~. ~. O0 O. qO. 112. q. 5. 5, , 1;, ,00 O, ~; , 11~, 5, 4, 5, }. 1 o00 O, .00 3. 5. PAGE .00 8'. 4. 3. ~. · · 1 .00 .00 1;, ,00 O. 0.00 8 ~. 4. 4, O, O. 38. :Jq'. ..'3, 4. 4. B ! .00 O. ,08. 2. 1. 1. 3. 2. 2. CHEVERON SCU $1-8 ........ G~-'I-"'A N 'D--C-/~'[ ~ ........... OEP'tN .................. ~92'i-; ? .............. 8 1; o o00 O. 35. 85. ~. ~. ~. 8 12 o ,00 O. 37. 90, ~o ~o ~o 8 .00 O, , 87, ~. ~. ~, 8 7. 5. 6. 6. 5. 5. 6. 6 · 6. ', I0, 9. , 7. 0. 9(. 6. 6. 6. 81. 5. 5. 5. 7~ 5. 6. 5, 7. 6, 6. 5. 5. G. 5. 9. 8. 15. 8. 9. 5, 5. 6. .00 .00 O. 38. .00 ~5. 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C-~-[-i= ........ D-~-N ....... D£-N-P ................. '~N ........ --~-'--'-"~:~-0-~ ........ "-~"i~EM''~' 1 O. 0.00 O. 37, 91 1 , 0,00 O. O. 1 0.00 O. 38. 9i 1 ,00 O, · l; ,00 O, ,00 O, 9 O. 12, O. 0.00 O. 30. 66, 4. 4. 4. 9 · 1;. .00 O. 34, 90. .00 O, 97, 4. ~, ~, 6. ~e PAGE ).15 £HEVERON USA INC. SCU 51-8 ...... -G'~- ................. ~"O"7'Z"; ............... 3~'; ................... ~'0'72; ...................... 29'; .00 O. 6. 6, 6. 5. 5. 5. 60 6e 9 ~ .0o O. 50. 90. 9 5. 4. ~. 9 4. 5. 5. '. 9 3, 3. ~, 3, 5. PASE l~G O. 0,00 O. 2, 95, 4. ,00 O. 8. 86, ~. · 00 O, O. 86. ~. ,5,, ~. 5. 5. ,00 O, ,00 O, ,00 O, ~, 6, 5, ?. 7. 8, 10, 10. !5. 1G, 95, 5. 6. ,00 .00 .00 Ot 31, 86, ~, 3, 86, ~. 3. 66, ~. ~, PA~E CHEVERON USA INC. SCU ~-8 RI-AND-"CAE'I .... ARE-RUN' WITH'~ BHC" -AC ..... IM" THE ~' lOWER '~ 'SECT'i-ON'~B~'O~ .......i05-~0-6-'FT; .............................................. .................. DEPTH .................. ............................ PT .............. 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O. O, O, O. O, DIRECT D)GITAL LOGGING RECEIVED Alaska Oil & Gas Cons. Commission Anchorage COMPUTER PROCESSED ANALYSIS Comp.an:¢ CHEVRON USA, INC, l.,.Imt 1 SOLDOTNA CREEK UNIT #~1-8 F i ¢_ i d SWANSON R i',,,'ER D~TE OF JOB; u, ~,_, 8_, C o u n t :¢ K E fi A I State ALASKA Count. c? USA C:L I ENT FORMAT DATA TAPE LOG INFORMATION ~,'=~TANDARD FORMAT ( L I 0845,00 Nar:e: SOLDOTNA CREEK LiH!T ~SI-8 F'ield: SWANSON RIVER DATE OF ,JOB: 07-28-86 Data: Time: P..~ge'..: 5 AI..H_~ i 986 I :,48 PH TUE, 1 L. TAPE RECORD'~ HEADER RECORDS REEL HEADER name: ~-.:~]5F 01 Previoos reel: bate: 862u~/~.5 Comments: Origin: P ,a g e '2 Reel name: ~5~6~;$ Contir',~mtion ~: O~ Service name: &;~._FO~ Previous tapm~ Comments: Origin: Tape name: Continuation ~: 01 :.~=+;** FILE HEADER Film nam+::: ~.~GSFOi . OOt Maximum iength: 1024 HERDER RECORD© Vet-sion ~: File 'type: LO Previous file: Date: H N E M CN COUN STAT CTRY SECT TOWN RANTS EKe, EDF EGL PD LMF DHF RUN LCC SON LUN FL LUL EN~I bJ ! TN DD DL. TLi TCS TLA8 BHT MRT MT MViS RH RHF MFST MFSS RMC H C S T MCSS I NFORMAT 1 ON RECORDS CONTENTS UNIT CHEVRON IJSA, INC ................. oOLDOTN~ _.RE~:.K UNTT I-8 ................ c,W~i,iSON RI';,'ER DATE OF JOB ~ ,]?-28-85 ............... KENA i .................................... AL.~SKA ................................... USA ................................... O?N ............................................. 09t. d ........... ,., ................................ __ i 55 O0 0 ...................................... k ~ i54 000 ......................................... FT 128 500 ......................................... k ~ KB .............................................. k.'B .................................................... ,.,5', 1 6 i~ ~.t-, k i NG .................................... STERL I NG h. IAI TE LOGAN,."ECK .................................... i085~,000 ............................................... FT i 0'8~4 000 .......................... FT 8800 ~ 000 ............................................... F'~T FT HR HR DEGF DEGF .... CP ....... 0 H H H , OHHM , DEGF . 0 H ['i M , DEGF TYPE CATG S i ZE CODE 0 0 40 65 0 0 ,40 65 0 0 40 65 0 0 20 65 0 O 20 65 0 0 20 65 0 0 2 65 0 0 S 65 0 0 S 65 0 3 4 68 0 3 4 68 0 3 4 6 E: 0 S 2 :55 0 3; 2 65 0 3 2 ~.:, 5 0 0 2 79 O O 2 7'-} 0 0 i 0 65 0 0 10 65 0 0 20 65 O O 20 65 0 0 20 65 0 0 2 0 65 0 3 4 68 0 3 4 68 0 3 4 68 0 3 4 68 0 :-::'. .4 68 0 4 4 68 0 i 4 68 0 i 4 68 0 2 20 65 0 2 20 :65 0 2 4 68 0 2 4 68 0 2 4 68 0 2 4 68 0 2 i2 65 O 2 4 68 0 '2 4 6 8 0 2 12 65 COMMENT RECORD¢:,,, :~::s This LIS tape L,,ms ,.,~rit. t-mn bp Gmar-hm.~-t indu._--.t, rims Wir-miine Ser. vi,zes. :+::~- All cu~'vm and tool mnemonics used ar.~z those which most closml,/ mat,-h ~+:-'~ m..,¢. G.marhar. t curve and tool mnemonics. ~EARHART TO SCHLLi~lBERGER MHEM SERVICE UHtT MNEM SERVICE UNIT DEF'TH FEET DEPT FT GR MERGE GAPt GR MERGE GAP! C:CL. MERGE MV CCL MERGE MV FCNL MERGE CPS FCNL MERGE CPS NCHL MERGE CPS NCNL MERGE CPS NPHS COMPUTED SSPU NPHI COMPUT PU RAT COHPUTE[:, NRAT COMPUT .... DATA ENTRY ~:~:~'. ENTRY BLOCK LEGEND TYPE DESCRIPTION 0 Terminmtor ( no more mntrims ) FORMA T SPEC I F I CA TYPE SI~E~ CODE 0 i 66 TIONS DRTA FORMRT '+;:+~:~.:+: DATUM SPECIFiCATiON 8LOCKS :~.:~;.~e-' SERVICE SERVICE AP1 AP1 AP1 AP1 FILE MNEH ID ORDER ~ UNiT LOG TYPE CLASS MOD # DEPT .~¢516i~ FT 0 0 0 '0 0 GR MERGE ..75i6i3 GAPi 0 54 i 0 0 CCL MERGE :.~5i6t~ MV 0 150 i 0 0 FCNL HERGE ._516i7 ..P~, 0 78 ~i 0 0 NCNL HERGE 35t6iS CPS 0 78 SO 0 O' NPHi COHPUT ~5i 6i ~, PU 0 i '~ ~2 *' 0 0 NRAT COHPUT ~= · _* o I 6 t =' 0 0 0 0 0 ~:,PEC 1 F I VA T 1 ONe, PRC # SiZE LVL SMPL RC '4 0 1 68 4 0 1 68 4 0 I 68 4 0 i 68 4 0 1 68 4 0 ! 68 4 0 t 68 PROCESS Ii',IDiCATORS DEPT DA TA RECORD"". o GR CCL FCNL HCNL HPHI NRAT i0845,000 0.000 0.000 0,000 0,000 ;.-29,54 0 -999, ;---' 50 V r ,4,.,, 000 45 °00 77t .300 674,700 1 054 1 0645,000 91 ,900 270 366.200 408, 000 30, 1 .S n 1 t4.7 t :~45 000 52,500 · .300 500.300 517,600 2¢,. 060 i 0445, 000 4t ,400 01 t00 '233,200 34.630 i 2i0 0345,000 ,~00 '2t2,600 253.500 3,4.470 1 '13.3 10245,000 42,600 ,240 i69,500 242.700 53,590 i 34i 10t45,000 900 ,320 8,00 255.100 36 6i0 1 274 i 0045, 000 45 400 1~4 '~00 ~.4.~ 300 42 9i0 1 .714. 9945,000 44 '200 i , 't 90 '-'0-~ 500 260,900 43 000 9845,000 70 700 2,060 245,500 294,600 1 24'2 ~ ,. 4.... 000 .7.43 500 ,400 149,700 208,600 54 210 I 368 9645, 000 6i 100 i.010 ~00,200 287,800 .., ._, 440 446 9545,000 35 800 ,770 167,700 225.300 45 770 1 31;3 9445, 000 40 500 ,300 i6i,900 223,400 5i 560 t ,4 r~ 7 93.= 4,.,, 000 39 i00 i .620 186,700 100 48 460 I 294 RECORDC:. DEPT GR CCL FCNL NCNL NPHi NRAT P a g e 9245,000 4'1 , 900 , .T.42 0 243,200 ~0i ,i00 38,680 284 9i45, 000 43,200 ,240 134,800 197,000 55,460 1 ,561 9045,000 44,800 .670 i7i,700 234.400 52.560 t ,409 8945,000 40,700 ,320 I43.9:00 207,900 56,300 I ,570 8845,000 42,300 ,260 139,500 200.400 .~7.210 i ,409 F'il¢ nam¢~ &GSFOJ , Maximum imngth: 1024 Fiim t.,.:.,p¢: LO TRA I LER REUORDo Vmrsion #: Nmxt f'ilm: Dat~; P ..:-~ g 6: iO