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Home My WebLink About171-0211. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 11,551' 11,311 (fill) Casing Collapse Structural Conductor Surface 1,580 psi Intermediate Production 3,830 psi Liner 10,490 psi Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Ryan LeMay, Operations Engineer Contact Email:ryan.lemay@hilcorp.com Contact Phone: 661-487-0871 Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Other: Rod Pump, Repair Noel Nocas, Operations Manager 907-564-5278 Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 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 and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY AOGCC USE ONLY 10,140 psi Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): Subsequent Form Required: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 FEDA028990 171-021 50-133-20231-00-00 Hilcorp Alaska, LLC Proposed Pools: 3800 Centerpoint Drive, Suite 1400 Anchorage, Alaska 99503 L-80 & N-80 TVD Burst 10,313' 6,340 psi 3,062' 70' 3,063' MD 5" 10,500 - 10,725 3,130 psi 69'70' 3,063' October 15, 2025 11,549'1,266' 2-7/8" 10,826' 10,491' Perforation Depth MD (ft): 10-3/4" Soldotna Creek Unit (SCU) 13-34N/A Same 9,806'7" ~1435psi Swanson River Hemlock Oil Size 11,213 - 11,445 10,491' N/A Length See schematic See schematic 10,828' 11,503' 10,781' 18" No Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 9:39 am, Oct 09, 2025 Digitally signed by Noel Nocas (4361) DN: cn=Noel Nocas (4361) Date: 2025.10.08 15:48:00 - 08'00' Noel Nocas (4361) 325-617 If rod string is to be left across the wellhead overnight, either the well must be manwatched or the polished rod stabbed back on to the rod string and the packoff/stuffing box reinstalled. A.Dewhurst 09OCT25 10-404 BJM 10/9/25 DSR-10/10/25 10/13/25 Well Prognosis Well: SCU 13-34 Well Name: SCU 13-34 API Number: 50-133-20231-00 Current Status: Offline Oil Producer Permit to Drill Number: 171-021 Regulatory Contact: Donna Ambruz (907) 777-8305 First Call Engineer: Ryan LeMay (661)487-0871 (M) Second Call Engineer: Scott Warner (907) 830-8863 (M) (907) 564-4506 (O) Maximum Expected BHP: ~ 2446 psi @ 10,114 TVD (Based on SCU 43A-33 BHP Survey 8/18/2018) Max. Potential Surf. Pressure: ~ 1435 psi (0.1 psi/ft gas gradient to surface) Brief Well Summary Soldotna Creek Unit 13-34 is a rod pump well with a Rotoflex pumping unit. The pump and rod completion has not been changed on this well since 2010. In late June of 2025, it is suspected the rod string parted shallow. The well has been offline since. The purpose of this Sundry is to fish and pull the existing rod string and rod pump from the well and replace with new rod completion and pump. Notes Regarding Wellbore Condition Prior to going offline, last well test was completed on 6/9/2025 and the well was producing 46 gross bbls fluid (8 bopd / 38 bwpd). Echometer fluid level measurement of 5735 last taken in June 2025. Workover Rig Procedure: 1. Ensure Rotoflex surface pump unit is uncoupled, skidded back, and the motor is LOTO. 2. MIRU Hilcorp Rig # 401. 3. Bleed down any residual IA pressure and bullhead a minimum of 1x IA casing volume with produced water (~8.4 ppg). 4. Bleed down any residual tubing pressure and bullhead a minimum of 1x tubing volume with hot produced water (~8.4 ppg). a. Note: if pump on seat and unable to pump down tubing, a tubing volume will need to be bullheaded once pump is unseated. 5. Verify well static and no flow prior to ND pack off. 6. ND remaining Rotoflex components and pack off. 7. NU Rod stripper head. 8. PU on rods and pull parted rod string from parted depth to surface (rod part suspected shallow). 9. PU rod fishing assembly, RIH and latch onto parted rod string. a. If pump was on seat in step 4 above, pump a minimum of 1x tubing volume with hot produced water (~8.4 ppg) in this step prior to coming out of the hole with the remaining rod string and pump. 10. Pull remaining rod string and rod pump fish. 11. If deemed necessary, rig up slickline unit and perform drift and tag through existing tubing completion. 12. PU new rod pump / rod string and run new rod string completion. 13. Space out rods, land pump, and install polish rod. Well Prognosis Well: SCU 13-34 14. PT tubing to 1000 psi. 15. ND rod stripper head and install surface equipment. 16. RDMO Hilcorp Rig # 401. 17. Roll up Rotoflex surface pumping unit, recouple, and remove LOTO. 18. Return well to oil production. Attachments: 1. Actual / Proposed Schematic (Proposed schematic same as current actual schematic with improved design adding sinker and stabilizer bars at the bottom of the new rod string design) Downhole Revised: 09/03/10 Updated by DMA 04-03-19 Soldotna Creek Unit Well SCU 13-34 Completed: 09/03/10 PTD: 171-021 API: 50-133-2021-00 ACTUAL SCHEMATIC TD = 11,551 PBTD = 11,503 MAX HOLE ANGLE = 32 deg. @ 7,972 RKB: 145 / GL: 128.5 AMSL KB THF: 16.5 1 PERFORATIONS Zone Top (MD) Btm (MD) Top(TVD) Btm(TVD) Amt Comments G-zone 11,213' 11,233'10,500 10,51920' Perf'd 08/16/01 H1 11,290' 11,302'10,575 10,58612' Perf'd 12/17/71 H2 11,310' 11,328'10,594 10,61218' Perf'd 12/17/71 H3 11,341' 11,352'10,624 10,63511' Perf'd 12/17/71 H4 11,362' 11,381'10,645 10,66319' Perf'd 12/17/71 H4 11,381' 11,400'10,663 10,68119' Perf'd 12/17/71 H5 11,414' 11,445'10,69510,725 31' Perf'd 12/17/71 H1 10 8 9 G-Zone H2 H3 H4 H5 CASING DETAIL Size Wt Grade ID Conn Top Btm 18----Surf 70 10 ¾40.5 K-55 10.050 BTC Surf 3,063 723 N-80 6.366 BTC Surf 2,538 726 N-80 6.276 BTC 2,5384,343 729 N-80 6.184 8RD 4,343 6,783 729 P-110 6.184 BTC 6,78310,491 518 N-80 4.276 BTC 10,28311,549 TUBING 2-6.4 L-80 2.441 IBT 16.510,152 2-6.4 N-80 2.441 IBT 10,15210,313 3 5 7 6 2 DV @ 1678DV @ 1060DV @ 6641A B C I II III IV 11 TOL 10,283 12 H4 Tag fill 11,311 SLM 8/12/01 1 4 JEWELRY DETAIL No. Top Btm Length ID OD Item A 1.19' 40.90'39.71' 1.500 Polish Rod (spaced out 7.17' above stuffing box w/ pump 3.33' off btm). 41' 3,038' 2,997.38'1.0 2.025 1" EL Sucker Rod, w/ Slimhole Class T coupling w/ (3) 2.25" R&M Stealth XL AF Rod Guides per rod 3,038' 3,964'925.74' 0.88 1.812 7/8" EL Sucker Rod, w/ Slimhole Class T coupling w/ (3) 2.25" R&M Stealth XL AF Rod Guides per rod 3,964' 6,566' 2,602.08'0.88 1.812 7/8" EL Sucker Rod, w/ Slimhole Class T coupling w/ (12) 2.25" R&M Stealth XL AF Rod Guides per rod 6,566' 10,094' 3,527.82'0.75 1.625 3/4" EL Sucker Rod, w/ Slimhole Class T coupling w/ (3) 2.25" R&M Stealth XL AF Rod Guides per rod B 10,094' 10,139'45.00' 2.15 2.34 1-1/2" RHBC Dbl valve Pump w/ Stabilizer Bar. (Set 9/03/10) C 10,139' 10,200' 60.80' 1.278 1.66 1.92 1-1/4" (1.660" OD) 1-1/4" IBT B x P w/ ported bull nose 16.50' 17.30' 0.80' 2.441 - Seaboard International Tension Hanger (2-7/8" EUE Lift threads, CIW H BPV profile) 1 10,139' 10,140' 1.11' 2.280 3.062 Cup Type Seating Nipple, 2-7/8 IBT 2 10,146' 10,152' 5.66' 2.875 4.688 4-11/16" Bowen Overshot 3 10,162' 10,165' 2.51' 2.280 3.062 Cup Type Seating Nipple, 2-7/8 w/ XO's to Butt 4 10,165' 10,171' 6.10' 2.441 2.875 Pup Joint, 6 x 2-7/8, 6.4#, N-80, Butt 5 10,171' 10,175' 4.15' 2.323 3.500 Ported Sub, 2-7/8", 7.2#, Butt BxP 6 10,175' 10,301' 126.14' 2.441 2.875 4 Joints of 2-7/8, 6.4#, L-80, Butt tbg 7 10,301' 10,302' 1.17' 2.188 3.500 Otis R Profile nipple, 2.188 w/ Butt BxP w/ Plug. 8 10,302' 10,308' 6.05' 2.441 2.875 Pup Joint, 6 x 2-7/8, 6.4#, N-80, Butt 9 10,308' 10,313' 4.91' 2.323 3.500 Ported Sub, 2-7/8", 7.2#, Butt BxP 10 10,313' 10,314' 0.78' 1.968 3.430 Baker Model "E" Anchor Latch w/o seals 11 10,314' 10,317' 2.78' 2.688 3.968 Baker Model "D", 32-26, Perm Packer. (Set 8/10/01) 12 11,314' 11,324' 10.00' - - Perforated Tubing I 11,309 Baker Scoop Head Guide II 11,331 Baker Mod FH Retrievable Packer III 11,406 Baker Mod FH Retrievable Packer IV 11,443Tubing Tail THE STATE Alaska Oil and Gas 01ALASKA Conservation Commission GOVERNOR SEAN PARNELL 333 West Seventh Avenue Mr. Chad Helgeson Operations Manager, North Kenai Area Hilcorp Alaska, LLC P.O. Box 244027 Anchorage, AK 99524-4027 RE: No -Flow Verification Soldotna Creek Unit 13-34 PTD 1710210 Dear Mr. Helgeson: Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 September 23, 2013 On March 18, 2013 an Alaska Oil and Gas Conservation Commission (AOGCC) Petroleum Inspector witnessed a no -flow test of Soldotna Creek Unit 13-34. The well is operated by Hilcorp Alaska, LLC (Hilcorp), completed as an artificially -lifted producer that relies on a rod pump system to bring production to surface. The AOGCC Inspector confirmed that the proper test equipment — as outlined in AOGCC Industry Guidance Bulletin 10-004 — was rigged up to the well and for flow to surface. During the flow monitoring period, there was no liquid production to surface and gas production was measured at rates less than 900 standard cubic feet per hour. Soldotna Creek Unit 13-34 meets the AOGCC requirements for a no -flow status determination. Hilcorp requested a safety valve system variance for its rod pump wells located in the Swanson River Field (Swanson River Unit and Soldotna Creek Unit) by letter dated December 31, 2012. In lieu of a surface safety valve (as required by 20 AAC 25.265), Hilcorp requests AOGCC consider an alternate configuration for well control equipment supported by the approved no flow status. The AOGCC decision regarding a required surface safety valve for Soldotna Creek Unit 13-34 will be addressed in response to Hilcorp's variance request. Sincerely, James B. Regg Petroleum Inspection Supervisor cc: P. Brooks AOGCC Inspectors • • MEMORANDUM State of Alaska AOGCC TO: Jim Regg 0113 DATE: 3/18/13 P. I. Supervisor' FROM: Bob Noble SUBJECT: Hilcorp Alaska LLC Petroleum Inspector No-Flow SCU 13-34, PTD 171-021 3/18/13 On arrival to the Swanson River Unit I met with Hilcorp Alaska representative Marty Guth and Hilcorp well operator Max Finch. We went over what the AOGCC requirements were for testing the well. I also had Marty show me the test equipment that he was going to use to do the no-flow test. Everything looked very acceptable. Max told me that the well had been open to atmosphere for approximately 12 hours. On arrival at the well I found it to still be open to atmosphere though a 2-inch hose. The well was found to still be bleeding some gas. Marty ask me if I still wanted to do the no-flow test on it. I told him yes because they had been bleeding the well and we would find out what it will do. Marty then hooked up his 1/2" test gauge and flow meter. He then lined up the IA and the tubing to flow through the test equipment. There was sign of flow after test equipment was hooked up. The test results are as follows: Time Pressures Status Flow Rate Remarks (psi) (scfm) 14:13 0/0/0 S/I well 0 15:00 7.5/7.5/0 Open well 9 15:05 3/3/0 Open 7 ' 15:35 2/2/0 Open 7 16:05 2/2/0 Open 10 • 16:20 2/2/0 Open 10 ' 16:21 2/2/0 S/I well 0 16:40 7/7/0 Open well 6 ' 17:00 5/5/0 Open 6 ' 17:40 3/3/0 Open 7 ' Pressures —tubing/inner annulus/outer annulus Flow Rate — standard cubic feet per minute (scfm) No fluid was seen at surface during the flow periods. The well produced a total of 1048 scf of gas during the test. Well pressures were not able to be bled to 0 psi through the 1/2" test equipment. Attachments: none U .r r a i 2013-031 8 No-Flow SCU 13-34 bn.docx Regg,-James B (DOA) From: Sent: To: Subject: Attachments attachments Jim Regg AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 Regg, James B (DOA) Monday, December 03, 2012 2:41 PM Grimaldi, Louis R (DOA) RE: SRU rod pump wells SSV SCU 13-34 No Flow.pdf; SCU 33-33 no flow.pdf , in - -(C5 4, From: Regg, James B (DOA) Sent: Monday, December 03, 2012 2:40 PM To: Grimaldi, Louis R (DOA) Subject: RE: SRU rod pump wells SSV Sc Lt } 54 No ftv i 'iesis L5/v a/eco i `612_71ZG0Z Appears I mis-spoke in my email yesterday (at least somewhat). According to 20 AAC 25.265(c)(8), both wells were required to obtain approval from AOGCC to continue operating without SSV by December 3, 2011. No request was received from then -operator Union Oil of California (Hilcorp did not take over field ops until Jan 1, 2012). SCU 13-34 (PTD 1710210) 1 researched this some more this morning; well has been approved (apparently) to operate without SSV based on passing no flow tests — see attached. I don't find the specific approval allowing the well to operate w/o SSV, but not sure why we would witness no flow tests unless it was our intention to allow. They would still be required to seek AOGCC approval to keep in operation. SCU 33-33 (PTD 1760560) Indicates that there was no flow test done but I don't find a record of Inspector witness, nor do I find specific approval allowing the well to operate w/o SSV. Same situation as SCU 13-34. Jim Regg AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 From: Regg, James B (DOA) Sent: Sunday, December 02, 2012 10:19 PM To: Grimaldi, Louis R (DOA) Subject: Re: SRU rod pump wells SSV no variance exists on rod pump wells so SSV is required by regulation. "Grimaldi, Louis R (DOA)" <lou.grimaldi@alaskayov> wrote: Jim, 1 During my tests on Thursday I came across two wells that were on rod pumps. These wells had Low Pressure pilots that would shut the rod pump mechanism down nearly immediately but the system lacked a Surface Safety Valve. One well 33-33 had a pressure regulator outside of the wing valve that kept a small amount of back pressure on the well (280 flowing/130 downstream regulator). The other well 13-34 was flowing at about 130 psi without any regulator present. I believe the regulators purpose was to keep gas from breaking out in the tubing at the pump. The IA and tubing were tied together with a "C section". I had them trip the LP sensor and watched the pump jack stop within 30 seconds. There was additional tubing/casing gas feeding the flowline and without a SSV there was nothing to bleed down to test. It would have been helpful if the well pressure fell off but it seemed to remain at the pressure that was present when the LPP was tripped. I have included a picture of 13-34 I had not heard of a variance for these wells so I would like to know if they are supposed to have a SSV. 13-34 171-0210 33-33 176-0560 Lou Grimaldi Alaska Oil and Gas Conservation Commission Petroleum Inspector Home 776-5402 Cell 252-3409 Lou. Grimaldi�Alaska.gov N po•-- - z� — .41�..''�r 143^'?'. ''e•4 �.. _ • • S 'et,( (3-34 t - 110210 Regg, James B (DOA) From: Grimaldi, Louis R (DOA) t2/Q 112/ Sent: Sunday, December 02, 2012 7:05 PM �� To: Regg, James B (DOA) Subject: SRU rod pump wells SSV Attachments: SCU 13 -34 wellhead 11 -29 -12 LG.jpg Jim, During my tests on Thursday I came across two wells that were on rod pumps. These wells had Low Pressure pilots that would shut the rod pump mechanism down nearly immediately but the system lacked a Surface Safety Valve. One well 33 -33 had a pressure regulator outside of the wing valve that kept a small amount of back pressure on the well (280 flowing /130 downstream regulator). The other well 13 -34 was flowing at about 130 psi without any regulator present. I believe the regulators purpose was to keep gas from breaking out in the tubing at the pump. The IA and tubing were tied together with a "C section ". I had them trip the LP sensor and watched the pump jack stop within 30 seconds. There was additional tubing /casing gas feeding the flowline and without a SSV there was nothing to bleed down to test. It would have been helpful if the well pressure fell off but it seemed to remain at the pressure that was present when the LPP was tripped. I have included a picture of 13 -34 I had not heard of a variance for these wells so I would like to know if they are supposed to have a SSV. 13 -34 171 -0210 33 -33 176 -0560 Lou Grimaldi Alaska Oil and Gas Conservation Commission Petroleum Inspector Home 776 -5402 Cell 252-3409 SCANN� �� i 2 2� 1 ' Lou.Grimaldi(c�Alaska.gov 1 i SCU 13 -34 — Rod Pump Artificial Lift PTD 1710210 11/29/2012 it 4 ti i < '' {, , 1 _i_ ,,_ 4. ,,, , Low Pressure : 7 ',7 --------- (PSLL) ressure (PSH and High ti. % PH Pilots sh down ... • r` + pump at 90 psi ) "' r A + < and 600 psi, ;., � ' r es p ectively j Ar. 11111104. t 0 ,, , .. , 4 ',' ir. frWille a k. r ill\ , _.....--- E I. Tilfr 4 . r r ... et , � y �, ' . #S M +rep • i lls ", Rupture disk "` + (1500psi) for ,1 w� r7 m , . ' : overpressure ..° - • ' �. �, ,� �� , � � - � �� protection, allows " '' produced flui to h recirculate in . ue? z , �, , ,r• = . , . ..�`� �-- _ _ _— �+ ' well the _Al th annu e us ( dow n no " # _ packer STATE OF ALASKA SEP 3 0 2010 iolq12ow ALASAL AND GAS CONSERVATION COMMISSO twd.an REPORT OF SUNDRY WELL OPERATION'M. AmE 1. Operations Abandon Li Repair Well Ll Plug Perforations Lj Stimulate Lj Other � Rod & pump changeout Performed: Alter Casing ❑ Pull Tubing Q Perforate New Pool ❑ Waiver ❑ Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Perforate ❑ Re-enter Suspended Well ❑ 2. Operator Union Oil Company of California 4. Well Class Before Work: S. Permit to Drill Number: Name: Development ❑✓ Exploratory El 171-021 Stratigraphic ❑ Service ❑ 3. Address: PO Box 196247, Anchorage, AK 99519 6\API Number: 50-133-20231-00 7. PropeNk Designation (Lease Number): 8. Well Name and Numberk ISoldotna FEDA028990 [Soldotna Creek Unit] CK Unit (SCU) 13-34 9. Field/Pool(s): Swanson River Field / Hemlock Oil Pool 10. Present Well Condition Summary: Total Depth measured 11,551 feet Plugs (measured) N/A feet true vertical 10,828 feet Junk (measured) 11,311 (fill) feet Effective Depth measured 11,503 feet Packer (measured) 10,314 feet true vertical 10,781 feet (true vertical) 9,642 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 70' 18" 70' 69' Surface 3,063' 10-3/4" 3,063' 3,062' 3,130 psi 1,580 psi Intermediate Production 10,491' 7" 10,491' 9,806' 6,340 psi 3,830 psi Liner 1,266' 5" 11,549' 10,826' 10,140 psi 10,490 psi Perforation depth: Measured depth: 11,213'-11,233', 11,290'-11,302', 11,310'-11,328', 11,341'-11,352', 11,362'-11,400', 11,414',-11,445' True Vertical depth: 10,500'-10,520', 10,576-10,587', 10,594'-10,612', 10,624'-10,635', 10,646-10,682', 10,695'-10,725' 6.4#L-80 / Surf-10,152'MD / Surf-9,497'TVD / Tubing (size, grade, measured and true vertical depth): 2-7/8" 6.4 #N-80 10,152'-10,313'MD 9,497'-9,641'TVD Baker Model D 10,314'MD Packers and SSSV (type, measured and true vertical depth): Packer (9,642'TVD) N/A N/A 11. Stimulation or cement squeeze summary: Intervals treated (measured): N/A � � ��Q Treatment descriptions including volumes used and final pressure: �' W OCT N/A 12. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 58 50 58 150 psi 145 psi Subsequent to operation: 99 37 77 125 psi 125 psi 13. Attachments: 14. Well Class after work: Copies of Logs and Surveys Run N/A Exploratory❑ Development0 Service ❑ 15. Well Status after work: Oil Gas WDSPL Daily Report of Well Operations X GSTOR ❑ WAG ❑ GINJ ❑ WINJ ❑ SPLUG ❑ 16. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 1310-231 Contact Stan Porhola 263-7640 Printed Na9WTimothy Title Drilling Manager ��C.``Brandenburg Signature �/'�J, Phone 276-7600 Date 9/28/10 Form 10-404 Revised 7/2009 f DMS OCT o 12010TH Submit Original Only Chevron Chevron - Alaska Daily Operations Summary Well Name Legal Well Name Lease Surface UW ChevNo Original RKB (ft) Water Depth (ft) SCU 13-34 SOLDOTNA CK UNIT 13-34 FEDA028990 5013320231 QA5344 143.00 - Primary Job Type Job Category Objective Actual Start Date Actual End Date Tubing Repair Major Rig 8/16/2010 Work Over (MRWO) Primary Wellbore Affected Wellbore UWI Well Permit Number SCU 13-34 501332023100 1710210 4111612011,10100:00 - 8117/ 010 00:00 Operations Summary Move rig from SCU 34-08. Bleed tubing and annulus to tank. Remove stuffing box and install rod BOPE. Test rod BOPE to 500 psi - test OK. Notified Jim Regg w/ AOGCC and Bill Diel w/ BLM of upcoming rod BOPE and potential rig BOPE test. AOGCC waived witness. 811712010 00:00 - 8/18120%00:00 Operations Summary Pulled rod pump off seat w/ 42K. Pump 3 bbl water to confirm. Pump 25 bbl paraffin inhibitor fluid down tubing to clean rods. POOH. UD rods. R/U slickline. RIH w/ 2.25" GR and tag Otis'R' nipple at 10,299' SLM. POOH. R/D slickline. R/U E -line. RIH w/ Micro Vertilog to 3,100' WLM. Decision from town to cancel log and pull tubing. POOH. R/D E -line. N/D Tree. N/U BOPE. 8/181201k*00 - 8/191 t0ft 0:00 ` Operations Summary Test BOPE to 250 psi low / 3000 psi high - test OK. Pump 25 bbl paraffin inhibitor fluid down tubing. Displace w/ 50 bbl 8.5 ppg lease water. Attempt to unset anchor latch in packer at 10,314'- no joy. R/U E -line. RIH w/ 2.25" jet cutter and cut tubing at 10,145' WLM. POOH. R/D E -line. 8/19120Itjl 0:00 - 8/2 00:00 v Operations Summary R/U pump truck. Pump 25 bbl paraffin inhibitor fluid down tubing. Displace w/ 20 bbl 8.5 ppg lease water. POOH & UD 10,145' of 2-7/8" N-80 tubing. Change 2-7/8" pipe rams to 3-1/2" pipe rams. Test to 250/3000 psi - test OK. P/U fishing BHA w/ 5.75" overshot. v 81201201-00:00 -4042 t 00:00 Operations Summary RIH on 3-1/2" workstring. Tag upon DV collar at 6,641' RKB. Unable to work pass POOH. UD 5.75" overshot. P/U 4-11/16" overshot w/ 5.25" guide. RIH. Circ 8.5 ppg lease water down tubing. Gas -cut crude returns to surface. 0,00:00 a fix. Operations Summary Tag fish at 10,150' RKB. Engage fish w/ overshot. Work 44 turns into E -Anchor. Jar on fish 8 times. Unable to release fish. Repeat turns and jarring for 4 times. Unable to release fish. POOH. UD fishing BHA. P/U 4.875" overshot w/ 5.25" guide. RIH. Engage fish at 10,150' RKB. R/U slickline. Recover fill at 10,292' SLM. Pull P -prong from plug in R nipple at 10,292' SLM. 8f2 2010ft- 8123/ _ ;s Operations Summary Pull plug body from R nipple at 10,292' SLM. Left bull plug on bottom of plug body in hole. Run 1.75" bailer to 10,304' SLM and recovered fill. Run 1.75" magnet to 10,304' SLM and recovered small metal debris including disk from jet cutter. Run 2.00" pump bailer to 10,304' SLM and no recovery. R/D slickline. POOH. UD 3-1/2" workstring. Change 3-1/2" pipe rams to 2-7/8" pipe rams. Test to 250/3000 psi - test OK. P/U overshot. RIH w/ 2-7/8" L-80 IBT completion tubing. 81231201`0 00:00,r••8(2e{t2010 00:00 Operations Summary RIH w/ 2-7/8" L-80 IBT completion tubing. Run overshot overfish at 10,140' RKB (10,147' Orig RKB). Space out and land hanger. Test hanger and mandrel seals to 250/3000 psi - test OK. Install BPV. N/D BOPE. N/U Tree. R/D and prep for rig move to SRU 21A-34. 8/2Tl2.1Q00:00,,28/201�'oQ:00';, t. Operations Summary RU Nitrogen unit to 7"x2-7/8" annulus. Pressure up on annulus to 1,500psi, displacing 129bbl fluid out tubing. Trap 1,500psi on annulus and RD Nitrogen unit. 81281201000:00 - 29/201 00.00 ` Operations Summary Rig up slickline, pressure test lubricator, Pump -N -Sub and Wireline valves 250 psi low and 2500 psi high. Swab 81 bbl fluid to 6,070' RKB, RIH and latch bull nose fish from anchor latch assembly at 10,314' RKB and POOH w/ same. RD slickline and secure well. j 01112010 6000'- 912126 0_-:00 ` Operations Summary Rig up slickline. RIH w/ 2.188" PR plug body. Attempt to set in R nipple at 10,301' RKB. POOH. Plug not set. Check shear pins - did not shear on plug lock or running tool. Re -set shear pins. RIH w/ same 2.188" PR plug body. Attempt to set in R nipple. POOH. Plug not set. Shear pins sheared on running tool, not sheared on plug lock. Replace shear pins and plug body packing. RIH w/ 2.188" PR plug body. Set in R nipple at 10,319' SLM (10,301' RKB). POOH. Plug set. RIH w/ P -prong. Set prong in PR plug in R nipple at 10,319' SLM (10,301' RKB). POOH. Prong set. Rig down slickline and secure well. 91311 0( :00=." 2010 00: . Operations Summary Move rig from SRU 21A-34. RIH with rod pump assembly on 3/4", 7/8", 1" tapered rod string, space out and seat pump at 10,094'. Fill tubing with water, pressure test pump and tubing to 950 psi for 30 min - test OK. R/D and prep for rig move to SRU 32A-33. Swanson River Field SCU 13-34 Chevron Actual Completion 9/03/10 API# 50-133-20231-00 RKB: 145'/ GL: 128.5' AMSL KB - THF: 16.5' TD = 11,551' PBTD =11,503' MAX HOLE ANGLE = 32 deg. @ 7972' CASING & TUBING Size Wt Grade ID Conn Top Btm 18" - ID - A Surf 70' 103 4" 40.5 K-55 10.050 BTC Surf 3063' 7" 23 N-80 6.366 BTC Surf 2538' 7" 26 N-80 6.276 BTC 2538' 4343' 7" 29 N-80 6.184 8RD 4343 6,783' 7" 29 P-110 6.184 BTC 6783' 10,491' Liner 60.80' 1.278 1 ' 1-1/4' (1.660' OD)1-1/4" BT B x P w/ported bull rose 1.92 16.50' 17.30' 0.80' 5" 18 N-80 4.276 BTC 10,283' 11,549' Tubing 2 10,146' 10,152 5.66' 2.875 4.688 4-11/16" Bowen Overshot 2-7/. " 6.4 L-80 2.441 IBT 16.5' 10,152' 2-'/e" 6.4 N-80 2.441 IBT 10,152' 10.313' SCU 13-34 Actual WBD 9-03-10.doc DRAWN BY: STP REVISED: 9/13/10 PERFORATION HISTORY JEWELRY DETAIL VO. Depth Top I Btm Length ID OD Item A 1.19' 40.90' 39.71' --- 29 1 .500 Polish Rod (spaced cut 7.17' above stuffing box w/ pump 333' off btm). f l 41' 3,038' 2,997.38'--- Pafd 12/17/71 1.0 1"EL Sucker Rod, WSlimholeClass Tcoupling w/(3)2.25"R&M 2.025 Steal 1h XLAF Rod Guides per rod 11,310' 3,038' 3,964' 925.74'--- H3 0.88 7B" EL Sucker Rod w/ Slimhde Class T ca ping w/ (3) 2.25" R8M 1.812 Steal ti XLAF Rod Guides per rod 11,352' 3,964' 6,566' 2,602.08' -- 11,362' 0.88 7,B" EL Sudker Rod w/ Slimhde Class T caping w/ (12) 225" RSM 1.812 Stealh XLAF Rod Guides per rod 19' 6,566' 10,094' 3,527.82'-- 11,400' 0.75 3k1" EL Sucker Rod w/ Slimhde Class T coupling w/ (3) 2.25" RSM 1.625 Stealth XL AF Rod Guides per rod B 10,094' 10,139' 45.00'--- 31' 2:15 1-1/2' RHBC DU valve Pump w/ Stabilizer Bar. (Set 9/03/10) C 10,139' 10,200' 60.80' 1.278 1 ' 1-1/4' (1.660' OD)1-1/4" BT B x P w/ported bull rose 1.92 16.50' 17.30' 0.80' 2.441 - Seaboard htematonaITen sonHangar (2-7/8'EUELitthreads, CIW 1 10,139' 10,140' 1.11' 2.280 3.062 CupTypeSeatng Npple 2-7/8" IBT 2 10,146' 10,152 5.66' 2.875 4.688 4-11/16" Bowen Overshot 3 10,162' 10,165' 2.51-1 2.280 3.062 1 Cup Type Seating NpplQ2-7/8"w/XO'stoButt 4 10,165' 10,171' 6.10-1 2.441 2875 Pup Joint, 6' x2-7/8", 6.4, N-80, Brit 5 10,171' 10,175' 4.15' 2.323 3.500 Ported Sulq 2-7/8', 7.2#, Butt BcP 6 10, 1761 10,301' 126.14' 2.441 2.875 4Jonts of 2-7/8", 6.4#, LSO, Butt tbg 7 10,301' 10,302 1.17' 2.188 3.500 Otis "R"ProfilenpplQ2.188"w/ButtBxPw/Pug 8 10,302' 10,308' 6.05' 2.441 2.875 Pup Joint, 6'x2-7/8", 6.4, N-80, But 9 10,308' 10,313 4.91' 2.323 3.500 Ported Su4 2-7/8", 7.2#, Butt BcP 10 10,313' 10,314 0. 781 1.968 3.430 Baker Wdel"E"Anchor Labh w/o seals 11 10,314' 10,317 2.78' 2.688 3.968 Baker Wdel"D",32-26,PermPadker.(Set8/10/01) 12 11,314' 11,324 10.00' - - Perforated Tubhg 1 11,309' Baker "Scoop Head Guide" I1 11,331' 1 jBaker Mod "FH' Retrievable Packer 111 11,406' 1 1 Baker Mod "FH' Retrievable Packer N 11,443' 1 ITubing Tail SCU 13-34 Actual WBD 9-03-10.doc DRAWN BY: STP REVISED: 9/13/10 PERFORATION HISTORY I interval Zone TOP Btm Ant Comments G -zone 11,213' 11,233' 29 Pafd 8/16/01 f l 11,290' 11,302' 12' Pafd 12/17/71 H! 11,310' 11,328' 19 71 Pafd 12/1771 H3 11,341' 11,352' 11' Pafd 12/17/71 I# 11,362' 11,381' 19' Pafd 12/17/71 I13 11,381' 11,400' 19' Pafd12/17nI IL -IL 111414' 11,445 31' Pafd 12/17/71 SCU 13-34 Actual WBD 9-03-10.doc DRAWN BY: STP REVISED: 9/13/10 f ~ i • ~~Q~~ 0~ Q[~Q~~{Q /~..a~a.~o...~ Timothy C. Brandenburg Drilling Manager Union Oil Company of California ' /~ P.O. Box 196247 ~ ~ . V Anchorage, AK 99519 - Re: Swanson River Field, Hemlock Oil Pool, SCU 13-34 Sundry Number: 310-231 ;~x, ~ ~a~~-~ `~~ ~ ~1 ~i ca 1~ ~ 0 ~+~ Dear Mr. Brandenburg: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. Chair ~d DATED this 3 day of August, 2010. Encl. .v~'~ ~ ~~'~~1/~D ~~lo ~~ STATE OF ALASKA ~~~~ ~ ~~~~ o~~oL~ZOto ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL~,~aska f~t3 ~ ~~„ ;, ~i&~;~,~ ~n nnr ~~ onn ,r~_z ._: ___ 1. Type of Request: Abandon ^ Plug for Redrill ^ Perforate New Pool ^ Repair Well ^ Change Appr ed Program ^ Suspend ^ Plug Perforations ^ Perforate ^ Pull Tubing ^~ Time Extension ^ Operations Shutdown ^ Re-enter Susp. Well ^ Stimulate ^ Alter Casing ^ Rod 8 pump changeout ^~ - 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Union Oil Company of California Development ^~ Exploratory ^ 171-021 - 3. Address: Stratigraphic ^ Service ^ 6. API Number: PO Box 196247, Anchorage, AK 99519 50-133-20231-00 - 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ^ No ~ Soldotna CK Unit (SCU) 13-34 9. Property Designation (Lease Number): 10. Field/Pool(s): FEDA028990 [Soldotna Creek Unit] ~ Swanson River Field /Hemlock Oil 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth ND (ft): Effective Depth MD (ft): Effective Depth ND (ft): Plugs (measured): Junk (measured): 11,551 10,828 11,503 10,781 N/A 11,311' (fill) Casing Length Size MD ND Burst Collapse Structural 70' 18" 70' 69' Conductor 3,063' 10-3/4" 3,063' 3,062' 3,130 psi 1,580 psi Surface 10,491' 7" 10,491' 9,806' 6,340 psi 3,830 psi Intermediate Production Liner 1,266' 5" 11,549' 10,826' 10,140 psi 10,490 psi Pertoration Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 11,213'-11,233', 11,290'- / 10,500'-10,520', 10,575'- 11,302', 11,310'-11,328', 10,587', 10,594'-10,612', 2.7/8„ / 6.4# N-80 10,314' 11,341'-11,352', 11,362'- 10,624'-10,635', 10,645'- 11,400', 11,414',-11,445' 10,682', 10,695'-10,725' Packers and SSSV Type: Packers and SSSV MD (ft) and ND (ft): Baker Model DPacker / N/A 10,314'MD (9,642'ND) / N/A 12. Attachments: Description Summary of Proposal Q 13. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^~ Exploratory ^ Development ^~ ~ Service ^ 10 14. Estimated Date for 8 15. Well Status after proposed work: / Commencing Operations: ~//S~Po Oil Q ~ Gas ^ WDSPL ^ Plugged ^ 16. Verbaf Approval: Date: N/A 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 Porhola 263-7640 Printed Name Timothy C. Brandenburg Title Drilling Manager Signature s~ _ - -Phone 276-7600 Date 7/28/2010 COMMISSION USE ONLY witness Sundry Number: ~/ O ~~~' re resentative ma l N tif is i th t diti f C C y : y omm s on so a a p ons o approva o on Plug Integrity ^ BOP Test [~ Mechanical Integrity Test ^ Location Clearance ^ . Other: ~ eS l ~ O~ t TO 3 0 0 0 ~ L:. Subsequent Form Required: (d - ~ C7 ~ • APPROVED BY ~f/ ~// O Approved by: COMMISSIONER THE COMMISSION Date: ux . ~uvIIW~ AUb U~ Form 10-403 Revised 12/2009 ~ ~ I ~ ~ ~ ~ j bmit in Duplicate Chevron • • Swanson River Unit Well #SCU 13-34 7/27/10 OBJECTIVE: • Pull rods and pump. Possible tubing pull. Run new tubing (if pulled). Run new rods and pump. PROCEDURE SUMMARY: 1 De-couple and roll back Rotaflex pumping unit, MIRU Key Energy Rig #3. 2 Strip rod surface equipment off well, NU rod BOPE, test same to 500psi & lay down polish rod. ~ 3 Pump chemical treatment to clean rods, Pull rods /lay down same. 4 Pull rods and pump assembly. Inspect rod string for indications of tubing wear. 5 Contingency: (If additional inspection of tubing is desired). a) RU Eline. Run Micro Verti-log tubing inspection to determine condition of tubing. 6 Contingency: (If changing out tubing or unable to pull rods & pump). a) Install BPV, ND tree, NU BOPE & test same 250psi low/ 3,000psi high, pull BPV. ~ b) PUMU landing joint, unseat mandrel from tension hanger, lower string to neutral & release anchor by working right hand torque to anchor. c) Pump chemical treatment to clean tubing. Pull 2-7/8" production tubing w/any unfished rods & pump and lay down same. d) RIH w/ 2-7/8" production tubing, anchor into packer @ 10,314', space out and land tubing in tension. e) Install BPV, ND BOPE, NU tree, test same, NU rod BOPE & test same to 500psi, pull BPV. / 7 PU rod pump, RIH on tapered rod string, land the pump, space out the rods, install the polish rod. 8 ND rod BOPE and strip surface equipment onto well. j' 9 RDMOL, roll up Rotaflex pumping unit and Re-couple. 10 Return well to production. Current BHP: 2,641 psi @ 10,500' TVD Max Downhole Pressure: 2,641 psi @ 10,500' TVD (Based on SITP =.150 psi, fluid level at 4,864' and a produced water gradient during perf of G-zone) MASP: 1,591~si (Based on a pressure gradient of 0.1 psi per foot of true vertical depth) SCU 13-34 REVISED BY: STP 7-27-10 Chevron API# 50-133-20231-00 • Swanson River Field SCU 13-34 Completed 8/10/01 Pump Replaced 8/30/02 Actual Com letion RKB: 145' / GL: 128.5' AMSL KB - THF: 16.5' CASING & T U B I N G Size Wt Grade ID Conn To Btm 18" - - - - Surf 70' 10'/<' 40.5 K-55 10.050 BTC Surf 3063' 7" 23 N-80 6.366 BTC Surf 2538' 7" 26 N-80 6.276 BTC 2538' 4343' 7" 29 N-80 6.184 8RD 4343 6,783' 7" 29 P-I 10 6.184 BTC 6783' 10,491' Liner 5" 18 N-80 4.276 BTC 10,283' 11,549' Tubin 2?/e" 6.4 N-80 2.441 IBT 19.67' 10,314' JEWELRY DETAIL NO. De Top pth Btm Length ID OD Kem A 2.11' 37.88' 35.77' -- 1.500 Fbl'sh Red (spaced ait T above stuffirg box w/ pump 2.22 off btm). 38' 3,05T 3,019.00' --- 1.0 2.025 1"ELSudcerRod,v/SimholeClassTcouplhgw'(3)2.25"R&M Stealfi XLAF Rod Guides perrod 3,057' 3,984' 927.00' -- 0.88 1 .812 7,8" EL Sucker Rod w/Simhde Class T caplhg w/ (3) 2.25" R8M Stealfi XLAF Rod Gui~s per rod 3,984' 6,590' 2,606.00' -- 0 88 1,812 7,8" ~ Sucker Rod w/ Simhde Class T cwplhg w/ (12) 225" R8N1 Stealh XLAF Rod Guirfis per rod 6,590' 10,115' 3,525.00' -- 0.75 1.625 3kl" A Sucker Rod w/Simhde Class T coiplhg w/ (3) 2.?5" R8M 3ealh XLAF Rod Guides perrod B 10,115' 10,159' 43.71' -- 2.34 1-1 /Z' RXBC DbI valvePumpw/ Statil¢er ~r (Set 8D0/02) C 10,159' 10,218' 59.46' 1.278 1.665 1-1 /4' (1.660' OD)1-U4" NPT B xP w/ ported bul nee 19.67' 20.30' 0.63' 2.441 _ Seaboard htematbnalTersbn Hangar (2-7/8' IBT Liftttreads, CM/ H BPV ofle 1 10,162' 10,165' 2.51' 2.280 3.062 Cup TypeSeathgNpplG2-7/8"w/XO'stoeutt 2 10,165' 10,171' 6.10' 2.441 2.875 Rip Joint, 6'x2-7/8", 6.4rE, N80, Batt 3 10,171' 10,175' 4.15' 2.323 3.500 Porfid Sub, 2-7/8", 7.2#,Butt BcP 4 10,175' 10,301' 126.14' 2.441 2.875 4Johtsof2-7/8", 6.4#, L-80, Bitttbg 5 10,301' 10,302' 1.17' 2.188 3.500 Otis "R" Profile npple, 2.188"w/Butt BcPw/ Plug. 6 10,302' 10,308' 6.05' 2.441 2.875 Pup Joint, 6'x2-7/8", 6.4~, NCO, Bu<t 7 10,308' 10,313' 4.91' 2.323 3.500 Pbrfid Sulk 2-7/8", 7.2#,Butt BcP 8 10,313' 10,314' 0.78' 1.968 3.430 BakerNbdel"E"AndiorLahhw/oseals 9 10,314' 10,31T 2.78' 2.688 3.968 BakerNbdel"D", 32-26,F~rmPadcer.(SetB/10/01) 10 1 1,314' 11,324' 10.00' - - Perbr3ed Tubhg I 1 1,309' Baker "Scoop Head Guide" I I 11,331' Baker Mod "FH' Retrievable Packer III 11,406' Baker Mod "FH' Retrievable Packer N 11,443' Tubing Tail PERFORAT ION HISTORY Irterval 7nne T Bim Ant Commerts G zone 11,213' 11,233' 20' PaFd 8/16J01 HI 11,290' 11,302' 12' Pafd 12! 17/71 I~ 11,310' 11,328' 18' Pafd 12/17/71 I-B 11,341' 11,352' 11' Pafd 12/17/71 I-kl 11,362' 11,381' 19' Pafd 12/17!71 III 11,381' 11,400' 19' Pafd 12/ 17!71 I$ 11,414' 11,445 31' Pafd 12/17/71 SCU 13-34 Actual WBD 8-30-02.doc DRAWN BY: STP REVISED: 1/26/10 TD = 11,551' PBTD = 11,503' MAX HOLE ANGLE = 32 deg. @ 7972' r Chevron API# 50-133-20231-00 • Swanson River Field SCU 13-34 Proposed Pro osed Com letion RKB: 145' / GL: 128.5' AMSL KB - THF: 16.5' CASING & T U B I N G Size Wt Grade ID Conn To Btm I g" - - - - Surf 70' 10'/<" 40.5 K-55 10.050 BTC Surf 3063' 7" 23 N-80 6.366 BTC Surf 2538' 7" 26 N-80 6.276 BTC 2538' 4343' 7" 29 N-80 6.184 8RD 4343 6,783' 7" 29 P-110 6.184 BTC 6783' 10,491' Liner 5" 18 N-80 4.276 BTC 10,283' 11,549' Tobin 2-'/x' 6.4 L-80 2.441 IBT 19.67' 10,314' JEWELRY DETAIL NO. De Top pth Btm Length ID OD Rem A 2.11' 37.88' 35.77' -- 1.500 Fbl'sh Rod (spao?d at T above stuffirp box w/ poop 2.22 off btm). 38' 3,05T 3,019.00' -- 1.0 2.025 1"ELSudcer Rod, v/ Simhole Class T couphg yr (3) 2.25" R&M Sealfi XLAF Rod Guides perrod 3,057' 3,984' 927.00' -- 0.88 1,812 7,8" l3 Sucker Rod w/ Simhde Class T couplhg w/ (3) 2.25" R8M Stealh XLAF Rod Guides per rod 3,984' 6,590' 2,606.00' -- 0.88 1 812 7.8" ~ Sucker Rod w/Simhde CJ•assT caplhg w/ (12) 225" RSM Stealh XLAF Rod Guides perrod 6,590' 10,115' 3,525.00' -- 0.75 1.625 3k1" EL Sucker Rod w/Simhde Gass T cauplhg w/ (3) 2.25" R8M Stealh XLAF Rod Guides perrod B 10,115' 10,159' 43.71' --- 2.34 1-1 /Z' RXBC DblvatvePumpw/ Stalil¢er Ber. (Set 8A0/02) C 10,159' 10,218' 59.46' 1.278 1.665 1-1 /4' (1.660' 00)1-1/4" NPr B x P w/ ported bul nose 19.67' 20.30' 0.63' 2.441 _ Seaboard htematonalTarsion Hang?r(2-7/8' IBf Lift tlreais, CNV H BPV o e 1 10,162' 10,165' 2.51' 2.280 3.062 Cup TypeSeathgNppl~2-7/8"w/XO'stoButt 2 10,165' 10,171' 6.10' 2.441 2875 Rip Joint,6' x2-718", 6.4#, NCO, But 3 10,171' 10,175' 4.15' 2.323 3.500 Porfid Suq 2-7/8", 7.2#,eutt BcP 4 10,175' 10,301' 126.14' 2.441 2.875 4Johtsof2-7/8", 6.4#, LSO, Hitttbg 5 10,301' 10,30T 1.17' 2.188 3.500 Otis"17' Profile: npple, 2.188"w/Butt BcPw/ Plug. 6 10,302' 10,308' 6.05' 2.441 2.875 Rip Joint, 6'x2-7/8", 6.4q, NCO, BLLt 7 10,308' 10,313' 4.91' 2.323 3.500 Porfid Sub, 2-7/8°, 7.2#,Butt BcP 8 10,313' 10,314' 0.78' 1.968 3.430 Bakerlvbdel"E"AndiorLathw/ose~s 9 10,314' 10,31T 2.78' 2.688 3.968 Bakertvbdel"D", 32-26,PermPadcer.(SetBl10/01) 10 1 1,314' 11,324' 10.00' - - Perfor3ed Tubhg I 11,309' Baker "Scoop Head Guide" I I 11,331' Baker Mod "FH' ReVievable Packer III 11,406' Baker Mod "FH' ReVievable Packer N 11,443' Tubing Tail PERFORAT ION HISTORY Interval Zone To Btrn Arnt Commeds G-zore 1 1,2]3' 11,233' 2d Pafd 8/1(x01 Hl 11,290' 11,302' 12' Pafd 12/17/71 H? 11,310' 11,328' 18' Pafd 12/17/71 H3 11,341' 11,352' 11' Pafd 1Z17l71 i-I4 11,362' 11,381' 19' Pafd 12/17(11 I# 11,381' 11,400' 19' Pafd 12/17/71 I$ 11,414' 11,445' 31' Pafd1Z17/71 SCU 13-34 Proposed WBD 7-O1-10.doc DRAWN BY: STP REVISED: 7/01/10 TD = 11,551' PBTD = 11,503' MAX HOLE ANGLE = 32 deg. @ 7972' Chevron • • Summary of Key Energy Rig #3 Specifics SCU 13-34 Workover The SCU 13-34 workover is to pull the rods and pump, evaluate and possibly pull the existing tubing string, run new tubing (if necessary), and run new rods and pump. The rig specifics are for the planned rig up on this well and are likely to change from well to well. Proposed Configuration Rig Model The rig model is a Hopper Hydra-hoist, Back-model GXXTA. Drawworks The drawworks are GXXTA-MD 10x42; w/ Sand Drum 15,000 ft - 9/16" sand line. Derrick The derrick is a telescoping double, with 260,000 Ib capacity, 30" crown sheaves and McKissick 30" 150 ton 73A traveling block. Pipe Handling The pipe handling system is a HydraWalk-hydraulic catwalk, 38' long, 5' wide, 5' high. The base beam is internally guided and load bearing. The beam is load rated with 102' derrick and 10,000 of 2- 7/8" tubing to 58 mph winds. BOP Specifications Annular, 5M 7-1/16" Hydril Double gate, 5M, 7-1/16" Shaffer Chasovoy w/ pipe ram (2-7/8" rams) and blind ram Mud Cross, 5M, 7-1/16" BOP Diagram See attached. Accumulator 120 gallon KOOMEY Accumulator System. Includes 5 functions with manual bypass and remote panel. Eight 15 gallon accumulator bottles. 200 gallon hydraulic tank with air operated hydraulic pump. Pits The pit consists of a 200 bbl tank partitioned into three isolatable compartments. An optional shale shaker is also available that is a 3'x4' Jr. Standard-hydraulic driven. Pump The pump is a National JWS-400 7"x4.5" Triplex rated to 5,000 psi on an independent skid. The pump will pull fluid directly from the pit. The discharge will be plumbed to kill line and an independent stand pipe line. Kill Line The Kill Line/Circulating Line consists of 2", 5,000 psi hose with Unibolt/Hub-flanged connectors. Key Energy Rig #3 Specs (SCU 13-34) rev0.doc 7/01/10 Chevron • • Kill Line Valves The kill line valves consist of 2 ea. manually operated, 2-1/16", 5M valves attached to the mud cross with co-flex hose with aUnibolt/Hub-flanged connectors. Choke Line The choke line consists of 2", 5,000 psi hose with Unibolt/Hub-flanged connectors. Choke Line Valves The choke line valves consist of 1 ea. manually operated, 2-1/16" 5M valve and 1 ea. automatically operated HCR valve that is attached to the mud cross with co-flex hose with aUnibolt/Hub-flanged connectors. Choke Manifold See attached. Choke Return Line/Diffuser Line The diffuser line will consist of 2", 5,000 psi hose with Unibolt connections. The line will run from the choke manifold to the diffuser tank. Diffuser Tank A diffuser tank will be placed adjacent to the mud pits with the capability of fluid transfer to the circulating system. Gas Detection There is a single gas LEL monitor and a single H2S monitor be placed at the work platform; and a single gas LEL monitor and a single H2S monitor at the shale shaker if used. PVT There is no PVT system for the circulation system on this workover rig, as is standard practice in this type of well service work. Key Energy Rig #3 Specs (SCU 13-34) rev0.doc 7/01/10 Chevron ~ BOPE Diagram SCU 13-34 Workover 7/06/2010 velar preventer, Hy~ 7 1/16 5M Flanged 3.08' 7.02' 2.27' 1.67' haffer Chasovoy 7 1/16 8 Pipe Ram stdd X 7 1 5M stdd ' Blind Ram O Mud Cross, 7 1/16 5M FE X 7 1/16 5M FE w/ 2 1/16 5M X 2 1/16 5M EFO Kill line 2 1/16 5M Choke line 2 1/16 5M Unibolt HCR Unibolt Chevron Swanson River 2010 Workover Program Rod BOPE 7/01/2010 Rod Plate for Landing Elevators Rod BOP, VBR 0"to 1" Rattigan From Pump ~ ~~~ 0 ~~~ ~~~ 0 To Choke Chel/ron ~ Swanson River 2010 Choke Manifold 07/01/2010 Blooey Line To Gas Buster ~ ~ Unibolt Connection 4 0 ~. Re: 10-404 for SCD 13-34 Rod Pump Change out ') Subject: Re: 10-404 for SCD 13-34 Rod Pump Change out From: Thomas Maunder <tom_maunder@admin.state.ak.us> Date: Mon, 08 Nov 200409:06:12 -0900 To: "Dunham, Diane E" <dunhamd@unocal.com> CC: Tim Brandenburg <brandenburgt@unocal.com> ) l:l...l:,,-: Q...2>... \ Thanks much Diane. Not sure why the documents you sent did not make the file when submitted. I appreciate your assistance on helping complete our record. Tom Maunder, PE AOGCC Dunham, Diane E wrote: Attached is the file you requested from Tim Brandenburg. Thank you. Diane Diane Dunham, Unocal Alaska 909 W. 9th Avenue, Anchorage, AK 99501 tel. 907-263-7604, fax 907-263-7884 SCANNED NO\i 0 8 200l} 1 of 1 11/8/20049:07 AM ) V ~I---\;:~ ) Unocal Corporation P.O. Box 196247 Anchorage, AK 99501 Telephone (907) 263-7805 \ '\ \ - O¡} ( UNOCAL-' l!,j~W.WIIJ,I\" ......m :A.laska October 1, 2002 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Attn: Cammy Taylor, Commissioner Re: Swanson River Form 10-404 SCU 13-34 Rod Pump Change Out Dear Commissioner Taylor: Enclosed for your review is the Report of Sundry Well Operations for the rod pump change out for Well SCU 13-34. The operations performed for this well are per our Application for Sundry Applicåtion Approvals dated August 21, 2002. The end of operations for this well was August 31, 2002. Please note that the attached wellbore schematic is corrected to to indicate completion equipment that was left in the well during the 2001 workover program. If there are any questions, please contact Tim Brandenburg at 263-7657. :in.cereIY, '" ~£) Tim Brandenburg Consultant ~7 P.O. Box 196247 Anchorage, AK 99519-6247 4. Location of well at suñace Conductor #21 67' FSL,1,889' FEL, Sec. 33, T8N, R9W, SM At top of productive interval STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Stimulate: Plugging:. Alter casing: Repair w;U: 5. Type of Well: Development: X Exploratory: - Stratigraphic: - Service: - ') ) , 1. Operations performed: ~. .'IIame of Operator Union Oil Company of California (UNOCAl) 3. Address Operation shutdown: Pull tubing: - -.-Perforate: Other: Rod pump change out 6. Datum elevation (DF or KB) 17' RKB 7. Unit or Property name feet At effective depth Soldotna Creek Unit 8. Well number SCU 13-34 9. Permit number/approval number 171-021/302-265 10. API number 50- 133-20231-00 11. FieldlPool Swanson River FieldlHemlock and Tyanek G At total depth 1 ,794' FSL, 630' FWL, Sec. 32, T8N, R9W, SM 12. Present well condition summary Total depth: measured true vertical 11,551' feet 10,828' feet Plugs (measured) Effective depth: measured true vertical 11,503' feet 10,781' feet Junk (measured) 10,474' 1 ,266' measured 11,213'-11,233'; 11,290'-11,302'; 11,310'-11,328'; 11,341'-11,352'; 11,362'-11,381'; 11,381'-11,400'; 11,414'-11,445' true vertical 10,500'-10,519'; 10,575'-10,587'; 10,594'-10,611'; 10,633'-10,644'; 10,645'-10,663'; 10,663'-10,682; 10,695'-10,725' Tubing (size, grade, and measured depth) . 2-718" 6.4# N-80 to 10,313' Packers and SSSV (type and measured depth) Baker Model "0" @ 10,313' (Used as Tubing Anchor for rod pump) 13. Stimulation or cement squeeze summary none Casing Structural Conductor Surface Intermediate Production Liner ~eñoration depth: Length Size Cemented Measured depth True vertical depth 53' 3,04S' 18" 1 0-3'4" 70' 3,063' 70' 3,063' 7" 5" 700 sx in 2 Stages 175 sx 10,491' 11,549' 9,80S' 10,826' Intervals treated (measured) none Treatment description including volumes used and final pressure none 14. Representative Daily Average Production or Injection Data Oil-BBL Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 85 129 37 170 1S0 Subsequent to operation 15. Attachments: Copies of Logs and Surveys run: Daily Report of Well Operations: X Oil: X Gas: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge: . 98 194 50 16. Status of well classification as: 180 175 Suspended: Service: S~ned: C /) Form 10-404 Rev 06115188 L- :if Title: Consultant Date: /0 -1-02- SUBMIT IN DUPUCA TE ) ) S:RU 13-34 Workover Daily Summary Workover to Replace Rod Pump Unocal Alaska Drilling Daily Summary Report SCU 13-34 WO 08/29/02 to 08/30/02 8/29/02 MIRU Pulling Unit. NU Rod Workover BOP. Unseat pump. Spot 20 bbls.of diesel w/55 gal. of NalcQ solvent. POOH hanging rods in derrick. 8/30/02 lD pump. MU new 1-1/2" pump & gas anchor. Test stroke pump. RIH w/pump & rods checking torque every 5 stds. RD rod table. Tag seating nipple @ 10,162'. Space out pump. ND Rod Workover BOPE. Install stuffing box. Fill tbg & test pump. Hang polish rod. Released rig at 13:00 hrs. 8/30/02 & moving to SCU 33-33. 8/31/02 Slide Rotaflex Pumping unit into position. Attach bridle to polish rod. Test well at 4 strokes per minute. Release well to production. - 1 - UNOCALe API# 50-133-20231-00 Orig. RKB = 16.5' ~ ~ -. @) § > @ Q > 0 0 ... [!] ~ ~ ) @] [!] .I: G.Zone C HI [:« IT] C - - ,'~>< @] C Ir::::D C II! r.JZ H2 H3 H4 HS ) ') Swanson River Field Soldotna Creek Unit Well No. 13-34 Completed 8/10/01 Pump Replaced 8/30/02 ~ctual Completio~ Size 18" 10 %" 7" 7" 7" Liner 5" Tubing -2-%" Casing Wt Grade & Tubing ID Top Surf Surf - --- Surf 2537' 4343 Btm 70' 3063' .. - 2537' 4343' . -.. 'ltJ,491'. 40.5 23 26 29 K-55 N-80 N-80 N-80 10.050 6.366. 6.276 6.184 I 18 I 6.4 I N-80 I N-80 I 10,283' I 11,549' I 14.70' I 10,314' I 4.276 I 2.441 JEWELRY DETAIL Depth .. NO. Top Btm Length ID OD Item 14.70' 16.50' 0.63' 2.441 - Seaboard Intemational Tension Hanger 2.11' 37.88' 35.77' - 1 500 Polish Rod (spaced out 7' above stuffing box wi pump 2. ŒJ . ,off btm). A 38' 3,057' 3,019.00' - 1.0 1" EL Sucker Rod, wi Slimhole Class T coupling wI (3) 2.2 0 .. ..... - 2.æ5 ..-- ;R&M .Stealth -Xl-AFRod. Guides per rod .88 7/8" EL Sucker Rod, wI Slimhole Class T coupling wi (3) 3,057' 3,984' 927.00' - 1.812 2.25" R&M Stealth XL AF Rod Guides per rod [!J 3,984' 6,590' 2,606.00' - .88 718" EL Sucker Rod, wi Slimhole Class T coupling wi (12) 1.812 2.25" R&M Stealth XL AF Rod Guides per rod 6,590' 10,115' 3,525.00' - .75 3/4" EL Sucker Rod, wi Slimhole Class T coupling wi (3) 1.625 2.25" R&M Stealth XL AF Rod Guides per rod B 10,115' 10,159' 43.71' - 2.15 1-1/2" RXBC Db! valve Pump wI Stabilizer Bar. 2.34 C 10,159' 10,218' 59.46' 1.28 1.665 1-1/4" (1.660" OD) 1~1/4" NPT B x P wI ported bull nose 1 10,162' 10,165' 2.51' 2.28 3.062 Cup Type Seating Nipple, 2-7/8" wi XO's to Butt 2 10,165' 10,171' _. -.6.10' .. 2.441 . -Z.875 Pùp Joint, 6' x 2-7/8", 6.4#, N-80, Butt 3 10,171' 10,175' 4.15' 2.323 3.500 Ported Sub, 2-7/8", 7.2#, Butt BxP 4 10,175' 10,299' 124.00' 2.441 2.875 4 Joints of 2-7/8", 6.4#, L-80, Butt tbg 5 10,301' 10.302' 1.17' 2.188 3.500 Otis "R" Profile nipple, 2.188" wI Butt BxP wI Plug. ~ .6 10,302' .- _1D,3OS' -.- - 6.05' .2.44.1 ... .2.815 P-up-Joint,.6'.x 2-7/S",6.4#.N..ßQ., Butt 7 10,308' 1 0,313' 4.15' 2.323 3.500 Ported Sub, 2-7/S", 7.2#. Butt BxP 8 11,442' 11,443' 0.78' 1.96 3.430 Baker Model "E" Anchor Latch wlo seals 9 10,314' 10.317' 2.78' 2.00 Baker Model "D", 32-26, Perm Packer. I II III IV 11,309' 11,331' 11,406' 11.443' Baker "Scoop Head Guide" Baker Mod "FH" Retrievable Packer Baker Mod "FH" Retrievable Packer Tubing Tail - -. -- m --'- - -- m --- - - -PERFORATION HISTORY Intenal Top I Btm Ant CoIm'ØÚ5 11,213' 11,233' 2CJ Ptrl'd 811&01 11,290' 11,302' lZ Perf'd 12/71 11,310' 11,328' 18' Perl'd 12/71 11,341' 11,352' 11' Perfd 12/71 11,362' 11,381' 19' Pafd 12/71 11,381' 11,400' 19' Perf'd 12/71 11,414' 11,44S 31' Perfd 12/71 DRAWN BY: sIt []!] [!ÿ] PBTD = 11,503' TD -= 11,551' MAX HOLE ANGLE -= 32 deg. @ 7912' SCU 13-34 Cunent dwg 8-30-02 Zone G-:zcne HI HI H2 H3 H4 H5 REVISED: 10/1102 RE: SCU 13-34 ') ) Subject: RE: SCD 13-34 From: "Brandenburg, Tim C" <brandenburgt@unocal.com> Date: Fri, 05 Nov 2004 08:23:38 -0900 To: Thomas Maunder <tom_maunder@admin.state.ak.us> \~\- é)d- r Tom, We will get right on this one as well. Tim -----Original Message----- From: Thomas Maunder [mailto:tom maunder@admin.state.ak.us] Sent: Thursday, Novembe'r.'''.''6.4'.~._..'''.2004 10: f§..-AM"."".'-.'."'.'''''...'''..-'''..'''.'.'''.'.''...''-'''.''.'''...............-............. To: Tim Brandenburg Subject: seD 13-34 Tim, I have another message regarding missing reports of work performed. I think you actually pulled the pump on this well in Aug - Sept 2002. >From my examination of our files, it doesn't appear that any work report was filed for that work or any that might have occurred since then. Would you have someone check on this and send in what is appropriate. Thanks, Tom 1 of 1 11/5/2004 8:33 AM SCU 13-34 Fluid Levels So\DO\~" CR..~k \..) ~'\ ~ Subject: SCD 13-34 Fluid Levels From: "Brandenburg, Tim C -Contract" <brandenburgt@unocal.com> Date: Tue, 3 Sep 2002 16:14:26 -0700 To: "'Tom Maunder'" <tom_maunder@admin.state.ak.us> ) \' ll-Oð--\ Tom, Evan told me that he had sent you the fluid level shot he made on Thursday prior to pulling the pump. We knocked the pump off seat at approx 4:30 pm Thursday and had the new pump in the ground and released from the well by noon Friday. The pump change out went extremely well. I was proud of the job as it represented (as far as I know) the first time that a true pulling unit has been used to pull and replace a rod pump in this state (some people have to bask in trivial glory)! The well was placed back on the pump Sunday and is currently pumping off. Once we have a stabilized rate, I will get the 10-404 in. Please call me if you have any questions. Thanks, Tim «SCU 13-34 Fluid Level.xls» Content-Type: application/vnd.ms-excel 13-34 Fluid Level.xls Content-Encoding: base64 1 of 1 11/4/2004 9:08 AM 8/20/2002 500 1500 2500 3500 =: - 0 :E 4500 .c .... Co CD 0 5500 ã) > CD ..J 6500 "C '5 u: 7500 8500 9500 10500 8/21/2002 . -~ . 'I:' . ~ :' ~.~. ~ . )i.; . . ~ ~ ..... 8/22/2002 . ~- . i: .. . ~-- ., '~~" . ., Swanson River SCU 13-34 Fluid Level After Shut In Date 8/23/2002 8/24/2002 8/25/2002 8/27/2002 8/26/2002 ----~ "'." ----- -j i. ! - ; ,: ! - ¡ - ¡ ,_. " . ,'" "';"'1: .. - . .' :; ',.:'- ','I:'. - :::~ . .." . ...:: ., . ,. 5247'':' 5161' -5039' ..1 .. . . I ."',:r.- 5213' - ..~- }'Oo -~ ." ¿. .- -. .~ Approx Fluid Level while on production ~ ~. ". , . ~ . ~> . :' h". ,.? ',. ,".. ;i~.' ; - . . ~ , , . '., ¥ . . . . . .. . . .. , .: ...__._------_.~....-......-........-,......................................................---.----_..................._.......... ...-......"....-----... -~"''''''''-'c_'''''- '-'-"--- -..-......-----....-- -..---.....--..-.. -..........-...-----_... ---"""""--""""-'" ......-....-._---.....'" -, 8/28/2002 8/29/2002 8/30/2002 -.--. - -- J --- ...-1..--.'----.------j ! . .4900', Fluid Level 7 hrs before knocking pump off seat [~):-I_lJ ¡~_~~yell. . ~ I i . ¡ .;h .m_:_. ---_0.] ~ i . ~ .~ j ¡ . : j --j ~ ¡ 1 \ ~ -..-fI ~. J ---- f 0 '+1 ---',~ SCU 13-34 Rod Pump Completion Fluid Level Data Date Fluid Level 8/21/2002 6500 8/22/2002 5530 8/23/2002 5213 8/24/2002 5247 8/25/2002 5161 8/26/2002 5039 8/29/2002 4900 ') ) \~\-\)d-' ~, -~ Unocal Corporation P.O. Box 196247 Anchorage, AK 99501 Telephone (907) 263-7805 UNOCALe J.'tt#WiiY. Alaska . <........<._.,<.~~~.:=:::.:-§~. October 1, 2002 Alaska Oil and Gas Conservation Commission 333 West ih Avenue Anchorage, Alaska 99501 Attn: Cammy Taylor, Commissioner Re: Swanson River Form 10-404 SCU 13-34 Rod Pump Change Out Dear Commissioner Taylor: Enclosed for your review is the Report of Sundry Well Operations for the rod pump change out for Well SCU 13-34. The operations performed for this well are per our Application for Sundry Application Approvals dated August 21, 2002. The end of operations for this well was August 31, 2002. Please note that the attached well bore schematic is corrected to to indicate completion equipment that was left in the well during the 2001 workover program. If there are any questions, please contact Tim Brandenburg at 263-7657. Sincerely, -2 - -J - Tim Brandenburg Consultant on~rd~'4\L ~ ". }.' ~ """.., ì 1'" ¡\ Ì=\ r\ llJ .. , .~ I \ RECEIVEO OCT 0 7 2002 Alaska on & Gas Cons. eomm\SS\On Anchorage I~ . ---...... STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown: Pull tubing: Stimulate: Alter casing: 2. Name of Operator Union Oil Company of California (UNOCAL) 3. Address P.O. Box 196247 Anchorage, AK 99519-6247 4. Location of well at surface Conductor #21 67' FSL, 1,889' FEL, Sec. 33, T8N, R9W, SM At top of productive interval At effective depth At total depth 1,794' FSL, 630' FWL, Sec. 32, T8N, R9W, SM 12. Present well condition summary Total depth: measured true vertical 11,551' 10,828' feet feet Effective depth: measured 11,503' feet true vertical 10,781' feet Casing Length Size Structural Conductor 53' 18" Surface 3,046' 10-3'4 " Intermediate Production 10,474' 7" Liner 1,266' 5" Perforation depth: measured Perforate: Other: Rod pump change out 6. Datum elevation (DF or KB) 17' RKB 7. Unit or Property name Plugging: _ Repair well: 5. Type of Well: Development: X Exploratory: Stratigraphic: Service: feet Soldotna Creek Unit 8. Well number SCU 13-34 9. Permit number/approval number 171-021/302-265 10. API number 50- 133-20231-00 11. Field/Pool Swanson River Field/Hemlock and Tyonek G Plugs (measured) Junk (measured) Cemented Measured depth True vertical depth 70' 3,063' 70' 3,063' 700 sx in 2 Stages 175 sx 10,491' 11,549' 9,806' 10,826' 11,213'-11,233'; 11,290'-11,302'; 11,310'-11,328'; 11,341'-11,352'; 11,362'-11,381'; 11,381'-11,400'; 11,414'-11,445' true vertical 10,500'-10,519'; 10,575'-10,587'; 10,594'-10,611'; 10,633'-10,644'; 10,645'-10,663'; 10,663'-10,682; 10,695'-10,725' Tubing (size, grade, and measured depth) 2-7/8" 6.4# N-80 to 10,313' Packers and SSSV (type and measured depth) Baker Model "D" @ 10,313' (Used as Tubing Anchor for rod pump) 13. Stimulation or cement squeeze summary none Intervals treated (measured) none Treatment description including volumes used and final pressure none 14. Representative Daily Averaae Production or Iniection Data Oil-BBL Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 85 129 37 160 170 98 194 50 16. Status of well classification as: 180 175 Subsequent to operation 15. Attachments: Copies of Logs and Surveys run: Daily Report of Well Operations: X Oil: X Gas: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge: Service: OCT 0 7 2002 Alaska OU& Gas Cons. Commtsaton Title: Consultant Anchorage Signed: L Form 10-404 Rev 06/15/88 C) Date: / ë:>.- 1- 02- SUBMIT IN DUPLlCAT~ r ~-; I' ,~ ~- SRU 13-34 Workover Dailv Summary Workover to Replace Rod Pump Unocal Alaska Drilling Daily Summary Report SCU 13-34 WO 08/29/02 to 08/30/02 8/29/02 MIRU Pulling Unit. NU Rod Workover BOP. Unseat pump. Spot 20 bbls. of diesel w/55 gal. of Nalco solvent. POOH hanging rods in derrick. 8/30/02 LO pump. MU new 1-1/2" pump & gas anchor. Test stroke pump. RIH w/pump & rods checking torque every 5 stds. RD rod table. Tag seating nipple @ 10,162'. Space out pump. NO Rod Workover BOPE. Install stuffing box. Fill tbg & test pump. Hang polish rod. Released rig at 13:00 hrs. 8/30/02 & moving to SCU 33-33. 8/31/02 Slide Rotaflex Pumping unit into position. Attach bridle to polish rod. Test well at 4 strokes per minute. Release well to production. - 1 - " API# 50-133-20231-00 ~, .~ Swanson River Field Soldotna Creek Unit Well No. 13-34 Completed 8/10/01 Pump Replaced 8/30/02 ~ctual Completio~ Orig. RKB = 16.5' Casing & Tubing ôo r-- ~ @) ;;:- o ;;:- o G-Zone ŒJ Hi H2 æJ H3 H4 æo H5 DYJ PDTD = 11,503' TD = 11,551' MAX HOLE ANGLE = 32 deg. @ 797 SCD 13-34 Current dwg 8-30-02 Size Wt Grade ID Top Btm 18" Surf 70' 10 %" 40.5 K-55 10.050 Surf 3063' 7" 23 N-80 6.366 Surf 2537' 7" 26 N-80 6.276 2537' 4343' 7" 29 N-80 6.184 4343 10,491' Liner 5" 18 N-80 4.276 10,283 ' 11,549' Tubing 2-Ys" I 6.4 I N-80 I 2.441 I 14.70' I 10,314' JEWELRY DETAIL Depth NO. Top Btm Length ID OD Item 14.70' 16.50' 0.63' 2.441 - Seaboard International Tension Hanger 2.11' 37.88' 35.77' - 1.500 Polish Rod (spaced out 7' above stuffing box wI pump 2. off btm). A 38' 3,057' 3,019.00' 1.0 1" EL Sucker Rod, wI Slimhole Class T coupling wI (3) 2. - 2.025 R&M Stealth XL AF Rod Guides per rod 3,057' 3,984' 927.00' .88 7/8" EL Sucker Rod, wI Slimhole Class T coupling wI (3) - 1.812 2.25" R&M Stealth XL AF Rod Guides per rod . 3,984' 6,590' 2,606.00' .88 7/8" EL Sucker Rod, wI Slimhole Class T coupling wI (12) - 1.812 2.25" R&M Stealth XL AF Rod Guides per rod 6,590' 10,115' 3,525.00' .75 3/4" EL Sucker Rod, wI Slimhole Class T coupling wI (3) - 1.625 2.25" R&M Stealth XL AF Rod Guides per rod B 10,115' 10,159' 43.71' 2.15 1-1/2" RXBC Dbl valve Pump wI Stabilizer Bar. - 2.34 C 10,159' 10,218' 59.46' 1.28 1.665 1-1/4" (1.660" OD) 1-1/4" NPT B x P wI ported bull nose 1 10,162' 10,165' 2.51' 2.28 3.062 Cup Type Seating Nipple, 2-7/8" wI XO's to Butt 2 10,165' 10,171' 6.10' 2.441 2.875 Pup Joint, 6' x 2-7/8", 6.4#, N-80, Butt 3 10,171' 10,175' 4.15' 2.323 3.500 Ported Sub, 2-7/8", 7.2#, Butt BxP 4 10,175' 10,299' 124.00' 2.441 2.875 4 Joints of 2-7/8",6.4#, L-80, Butt tbg 5 10,301' 10,302' 1.17' 2.188 3.500 Otis uR" Profile nipple, 2.188" wI Butt BxP wI Plug. 6 10,302' 10,308' 6.05' 2.441 2.875 Pup Joint, 6' x 2-7/8", 6.4#, N-80, Butt 7 10,308' 10,313' 4.15' 2.323 3.500 Ported Sub, 2-7/8", 7.2#, Butt BxP 8 11 ,442' 11 ,443' 0.78' 1.96 3.430 Baker Model "E" Anchor Latch wlo seals 9 10,314' 10,317' 2.78' 2.00 Baker Model "D", 32-26, Perm Packer. I 11,309' Baker "Scoop Head Guide" II 11,331' Baker Mod "FH" Retrievable Packer III 11 ,406' Baker Mod "FH" Retrievable Packer IV 11 ,443' Tubing Tail PERFORATION HISTORY Interval Zone Top Btm Am; Comœnts G-zone 11,213' 11,233' 20' Perl'd 8/16/01 HI 11 ,290' 11,302' 12' Perf'd 12171 HI 11,310' 11,328' 18' Perf'd 12171 H2 11,341' 11,352' 11' Perf'd 12171 H3 11 ,362' 11,381' 19' Perf'd 12171 H4 11,381' 11,400' 19' Perfd 12/71 2' H5 11,414' 11,445' 31' Perf'd 12171 2 DRAWN BY: sIt REVISED: 10/1/02 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Camille O. Taylor, Cot" DATE: Chair August 27, 2002 THRU: FROM: Tom Maunder, P. I. Supervisor Jeff Jones, SUBJECT: Petroleum Inspector No Flow SCU 13-34 PTD# 171-021 Swanson River Field Soldotna Creek Unit August 27, 2002: I traveled to Unocal's Swanson River Field and witnessed a No-Flow test on well SCU 13-34. Unocal representative Greg Merle performed the test today in a safe and proficient manner. Well 13-34 is a rod pump completion with gas ports to the annulus. Initial well bore pressures were 0 PSI on the tubing and 3 PSI on the annulus. The tubing was opened to atmosphere and no gas or liquid hydrocarbons were produced. The annulus was opened to atmosphere and the well flowed a slight amount of gas, which ceased comPletely in 2 minutes 55 seconds. The well was shut in and the tubing/annulus pressures were monitored for three hours. The tubing pressure remained at zero throughout the test and the annulus pressure increased from 0 to.2. PSI. Both were again opened to atmosphere and there was. no hydrocarbon production from the tubing and a slight amoUnt of gas from the~annul~s, Which again ceased completelY in .less than 3 minutes. During the No-Flow test this well was not capable of unassisted hydrocarbon flow and I recommend well SCU 34-13 in the Swanson River Field.be granted No-Flow status. Summary: Well SCU 34-13 meets the AOGCC requirements for no flow status. Attachments: Unocal well bore schematic (1) X Unclassified Classified Unclassified with Document Removed O I'L STATE OF ALASKA ALASKA AND GAS CONSERVATION 'OMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon: Suspend: Operaaon shutdown: Re-enter suspended well: ,,, Alter casing: Repair well: Plugging: Time extension: Stimulate: Change approved program: Pull tubing: Variance: Perforate: Other: X Rod Pump Change 2. Name of Operator 5. Type of well: 6. Datum elevation (DF or KB) Union Oil Company of California (UNOCAL) Development: X 17' RKB feet 3. Address Exploratory: 7. Unit or Property name Stratigraphic: P.O. Box 196247 Anchorage, AK ,9951~. Service: Soldotna Creek Unit 4. Location of well at surface ~-,/ ~./' 8. Well number v/ 67' FSL, 1,889' FEL, Sec. 33, T8N, R9W, SM SCU 13-34 At top of productive interval 9. Permit numb~,~' 171-021 At effective depth 10. APl number 50- 133-20231-01 At total depth 11. Field/Pool 1,794' FSL, 630' FWL, Sec. 32, T8N, R9W, SM Swanson River Field / Hemlock and Tyonek G 12. Present well condition summary Total depth: measured 11,551'Vj feet Plugs (measured) None true vertical 10,828' feet Effective depth: measured 11,503' feet Junk (measured) None true vertical 10,781' feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 53' 18" 70' 70' Surface 3,046' 10-3/4" 3,063' 3,063' Intermediate Production 10,474' 7" 700 sx in 2 Stages 10,491' 9,806' Liner 1,266' 5" 175 sx 11,549' 10,826' Perforation depth: measured 11,213'-11,233'; 11,290'-11,302'; 11,310'-11,328'; 11,341'-11,352'; 11,362'-11,381 '; 11,381'-11,400'; 11,414'-11,445' true vertical 10,500'-10,519'; 10,575'-10,587'; 10,594'-10,611 '; 10,633'-10,644'; 10,645'-10663'; 10,663'-10,682'; 10,695'-10725' Tubing (size, grade, and measured depth) 2-7/8", 6.4#, N-80 to 10,313' Packers and SSSV (type and measured depth) Baker Model "D" (Used as Tubing Anchor for rod pump) 13. Attachements Description summary of proposal: Detailed operations program: X BOP sketch: X .... , 14. Estimated date for commencing operation 15. Status of well classification as: 8/23/2002 16. If proposal well verbally approved: Oil: X 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. Signed: '*'"~.-..~ ~ ~~,-"' Title: ('w~ ~,_~,~"~-,~ ~'"'-"~ Date: ~;~ ..--~'~ '--~ ~-~,, _ FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness .... Plug integrity BOP Test Location clearance ~" E C ~ ~ Mechanical Integrity Test Subseque~form required 10- ~t_~"~_~,~, ~ Approved by order of the Commissioner Camm¥ Oechsli Taylor L;omm~ssmner " Date~/~/],,~1t'), ,_.. ~" / Form 10-403 Rev 06/15/88 SUBMIT IN TRI PL Unocal Alaska Business Unit Swanson River Well #SCU 13-34 UNOCAL(S) No. Preliminary Procedure Hang rods off and remove bridle. Slide RotaFlex Pump unit back from well. Remove 1 flowlines to below ground level. Install felt and liner for Pulling Unit containment. 2 MIRU Production Hoist. RU surface lines. Utilize landing rod, strip secondary BOPE, Riser, and Rod table over rods and NU to 3 tree. 4 Jar pump off seat. 5 POOH standing back rods PU/MU replacement rod pump & add shear-out above seal cups. Run rods land 6 pump. Space out rod string. 7 Space out rod string. 8 ND strip off rod running equipment off tree. MU polished rod. Release Rig. 9 Re-install Rotaflex Pumping Unit. SCU 13-34 Rod Repair AFE#.xls Page 1 of 1 8/21/02 UNOCALe API# 50-133-20231-00 Orig. RKB = 16.5' ctual Completio Swanson River Field Soldotna Creek Unit Well No. 13-34 Completed 8/10/01 Rods Ran 8/20/01 Casing & Tubing Size Wt Grade ID Top Btm 18" Surf 70' 10 %" 40.5 K-55 10.050 Surf 3063' 7" 23 N-80 6.366 Surf 2537' 7" 26 N-80 6.276 2537' 4343' 7" 29 N-80 6.184 4343 10,491' Liner 5" 118 IN-80 14.276 I 10,28y ]11,549' Tubing 2-7A" I 6.4 IN-80 I 2.441 I 14.70' I 10,314' JEWELRY DETAIL Depth NO. Top Btm Length ID OD Item 14.70' 16.50' 0.63' 2.441 - Seaboard International Tension Hanger Polish Rod (spaced out 7' above stuffing box w/ pump 2.22' 2.11' 37.88' 35.77' .. 1.500 off btm). 1.0 1" EL Sucker Rod, w/Slimhole Class T coupling w/(3) 2.25'" A 38' 3,057' 3,019.00' 4. 2.025 R&M Stealth XL AF Rod Guides per rod .88 7/8" EL Sucker Rod, w/Slimhole Class T coupling w/(3) 3,057' 3,984' 927.00' .... 1.812 2.25" R&M Stealth ×L AF Rod Guides per rod .88 7/8" EL Sucker Rod, w/Slimhole Class T coupling w/(12) 3,984'i 6,590' 2,606.00' 1.812 2.25" R&M Stealth XL AF Rod Guides per rod .75 3/4" EL Sucker Rod, w/Slimhole Class T coupling w/(3) 6,590' 10,115' 3,525.00' 1.625 2.25" R&M Stealth XL AF Rod Guides per rod 2.15 1-3/4" P, XBC Dbl valve Pump w/Dual Seating Cups w/ B 10,115' 10,159' 43.71', 2.34 Stabilizer Bar. C 10,159' 10,218' 59.46' 1.28 1.665 1-1/4" (1.660" OD) 1-1/4" NPT B x P w/ported bull nose 1 10,162' 10,165' 2.51' 2.28 3.062 Cup Type Seating Nipple, 2-7/8' w/XO's to Butt 2 10,165' 10,171' 6.10' 2.441 2.875 Pup Joint, 6' x 2-7/8", 6.4#, N-80, Butt 3 10,171' 10,175' 4.15' 2.323 3.500 Ported Sub, 2-7/8", 7.2#, Butt BxP 4 10,175' 10,299' 124.00' 2.441 2.875 4 Joints of 2-7/8", 6.4#, L-80, Butt tbg 5 10,301' 10,302' 1.17' 2.188 3.500 Otis "R" Profile nipple, 2.t88" wi Butt BxP wi Plug. 6 10,302' 10,308' 6.05' 2.441 2.875 Pup Joint, 6' x 2-7/8", 6.4#, N-80, Butt 7 10,308' 10,313' 4.15' 2.323 3.500 Ported Sub, 2-7/8", 7.2#, Butt BxP 8 10,3t 3' 10,314' 0.78' 1.96 3.430 Baker Model "E" Anchor Latch w/o seals 9 10,314' 10,317' 2.78' 2.00 Baker Model "D", 32-26, Perm Packer. '] G-Zone H1 -1 H2 "] H3 '] H4 PBTD = 11,503' TD = 11,551' MAX HOLE ANGLE = 32 deg. ~ 7972' SCU 13-34 Current dwg 8-10-01 PERFORATION HISTORY Interval Zone Top Btm Ant Conamnts G-zone 11,213' 11,233' 20' Perfd 8/16/01 - H1 11,290' 11,302' 12' Perl'd 12/71 H1 11,310' 11,328' 18' Peafd 12/71 H2 11,341' 11,352' 11' Peffd 12/71 H3 11,362' 11,381' 19' Pelfd 12/71 H4 11,381' 11,400' 19' Pelfd 12/71 -- H5 11,414' 11,445' 31' Perf'd 12/71 DRAWN BY: slt REVISED: 9/10/01 Unocal Corporation P.O. Box 196247 Anchorage, Alaska 99519 907-263-7671 UNOr. Wednesday, August 21,2002 Commissioner Cammy Taylor AOGCC 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 Swanson River Form 10-403 SCU 13-34 Rod Pump Change Out Dear Commissioner Cammy Taylor: Please find the enclosed 10-403 for the rod pump replacement in SCU 13-34. The well was completed as "packer less" rod pump completion during the 2001 Workover Program. The well was de-completed and new completion tubing ran with a drilling rig and the rod pump and rods were later installed with a 50 Ton Crane after the rig was moved off the well. As required in the Sundry Approval, a no flow was obtained on the well with an AOGCCwitness prior to installation of the pump. The well is completed in the Hemlock/G Zone. The BHP is estimated to be 1,900 psi at 10,500' TVD. Therefore the MASP is 850 psi based on full evacuation and a 0. lpsi/ft gas gradient. The BOPE configuration used last year and proposed this year is detailed in a letter.to Mr. Tom Maunder dated August 20, 2002. If you have any questions, please contact me at 263-7657. Sincerely, ~ ~ Tim Brandenburg RECEIVEP AUG 2'i 2002 Naska Oil & Gas Cons. Cornmlsslo~ Anchorage ORIGINAL UnocalCorporation ( .... P.O. Box 196247 Anchomge, ~aska 99519 907-263-7671 UNOr. Tuesday, August 20, 2002 Mr. Tom Maunder AOGCC 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 Swanson River Rod BOPE Configuration Mr. Maunder: We are preparing to perform work on two of our wells completed with Sucker Rod Pumps. The two wells (SCU 13-34 and SCU 33-33) were completed as "packer less" rod pump completions during the 2001 Workover Program. The wells were de- completed and new completion tubing ran with a drilling rig and the rod pump and rods were later installed with a 50 Ton Crane after the rig was moved off the wells. As required in the Sundry Approvals, a no flow was obtained on both wells with an AOGCC witness prior to installation of the pumps (See attached documents). For this years program we will utilize the Nabors Production Services Rig 26 which is a well servicing unit from Canada. The BOP configuration for the rod pump replacement is like that used last year for rod installation. The wells have a single set of permanent rams that are integrated into the well above the flow line and below the stuffing box. In preparation for the workover, the stuffing box will be removed and a second set of single rams (a workover ram) will be installed on top of the permanent set (See attached diagram). SCU 13-34 is planned as a rod pump change out only so this configuration would be applicable to the entirety of the work. SCU 33-33 could require that the.tubing, also be pulled. In order to accomplish this, the rod BOPE would be nippled down and an 11" Double gate and Annular would be rigged .up as per the proposal by Unocal dated August 8, 2002 and as modified by the AOGCC to date. During the tubing removal, the perforations will be open to the well and the fluid level will be below the surface as was the case during the initial installation of the completion in August of last year. If you have any questions, please contact me at 263-7657. Sincere. ly, ~'--~_.~ Tim Brandenburg R, EC !VFD A JG 20 2002 Alaska 0it anchorage UNOCAL ) Swanson River Field SCU 13-34 SCU 13-34 BOP Arrangement Running/Pullin~l Rods From Pump Rod Plate for Landing Elevators Rod BOP, with 1" x Blind Rams Rod BOP, with 1" x Blind Rams [To Choke From Tubing x Production Casing Annulus In this configuration the production tee has one outlet that is dedicated for pumping into the tubing. The other outlet (which is permanently plumbed to create a loop in the tubing by casing annulus) will be used to vent the tubing and or production casing annulus through the choke to the gas buster. Lease water will be added to compensate for the metal displacement of the sucker rods. The rod BOP's are configured to close on 1" to 0" (Blind). The current rod strings installed are 1", 7/8" and 3/4". SCU 13-34 BOPE 1 5/7/01 UNOCAL ) Swanson River Field SCU 13-34 Orig. RKB -- 16.5' Casinfl & Tubing Size Wt Grade ID Top Btm 18" Surf 70' 10 %" 40.5 K-55 10.050 Surf 3063' 7" 23 N-80 6.366 Surf 2537' 7" 26 N-80 6.276 2537' 4343' 7" 29 N-80 6.184 4343 10,491' Liner 5" 118 IN-80 14.276 I 10,283' 111,549' Tubing 2-7A'' 16.4 IN-S0 I 2.441 I 14.70' I lo,314' JEWELRY DETAIL Depth NO. Top Btm Length ID OD Item 14.70' 16.50' 0.63' 2.441 - Seaboard International Tension Hanger Polish Rod (spaced out 7' above stuffing box w/ pump 2.2 2.11' 37.88' 35.77' 1.500 off btm). 1.0 1" EL Sucker Rod, w/Slimhole Class T coupling w/(3) 2.2 A 38' 3,057' 3,019.00' 2.025 R&M Stealth XL AF Rod Guides per rod .88 7/8" EL Sucker Rod, w/Slimhole Class T coupling wi (3) 3,057' 3,984' 927.00' 1.812 2.25" R&M Stealth XL AF Rod Guides per rod .88 7/8" EL Sucker Rod, w/Slimhole Class T coUpling w/(12) 3,984' 6,590' 2,606.00' 1.812 2.25" R&M Stealth XL AF Rod Guides per rod .75 3/4" EL Sucker Rod, w/Slimhole Class T coupling w/(3) 6,590' 10,115' 3,525.00' 1.625 2.25" R&M Stealth XL AF Rod Guides per rod 2.15 1-3/4" RXBC Dbl valve Pump w/Dual Seating Cups w/ B 10,115' 10,159' 43.71' 2.34 Stabilizer Bar. C 10,159' 10,218' 59.46' 1.28 1.665 1-1/4" (1.660" OD) 1-1/4" NPT B x P w/ported bull nose ,. 1 10,162' 10,165' 2.51 2.28 3.062 Cup Type Seating Nipple, 2-7/8" w/XO's to Butt 2 10,165' 10,171'~ 6.10' 2.441 2.875 Pup Joint, 6' x 2-7/8", 6.4~, N-80, Butt 3 10,171' 10,175' 4.15' 2.323 3.500 Ported Sub, 2-7/8", 7.2#, Butt BxP , ,. 4 10,175" 10,299' 124.00' 2.441 2.875 4 Joints of 2-7/8", 6.4~, L-80, Butt tbg 5 10,30t' 10,302' 1.17' 2.188 3.500 Otis "R, Profile nipple, 2.188" wi Butt BxP w/Plug. 6 10,302' 10,308' 6.05' 2.441 2.875 Pup Joint, 6' x 2-7~8', 6.4~, N-80, Butt ...... 7 10,308' 10,313' 4.15' 2.323 3.500 ;Ported Sub, 2-7/8", 7.2#, Butt BxP "] G-Zone H1 3 H2 3 H4 PBTD = 11,503'TD = 11,551' MAX HOLE ANGLE = 32 deg. ~ 7972' SCU 13-34 BOPE PERFORATION HISTORY Interval Zone Top Btm Amt Cona~ats G-zone 11,213' 11~33' 20' Perf'd 8/16/01 H1 11,290' 11,302' 12 Peffd 12/71 H1 11,310' 11,328' 18' Perfd 12/71 1-12 11,341' 11,352' 11' Perf'd 12/71 It3 11,362' 11,381' 19' Perl'd 12/71 1-14 11,381' 11,400' 19' Perl'd 12/7i '- 1-15 11,414' 11,445' 31' Pert'd 12/71 2 5/7/01 UNd ,AL ALASKA RESOUI[ wELL SERVICE REPORT Date: Wireline Company: Work Being Done: Present Operations: - Supervisor: Wireline Unit Number: Zero Wireline at: Minimum Tubin~ ID: 8/7/2OOl Tag fill, set plug Pollard Wireline Inc. Tag fill & set Plug Complete R. Grainger Swanson Unit Tubin~l Han~ler 2.188" Well Number: Location: AFE# / Charge Code: Wireline Crew: Total Wireline Miles: Max Depth (KB): Well KB: Max Tool OD: scu 33-33 Swanson River AFE # 149641 D. Pollard/Smith 8 1O641' 16.8' 2.18" Time Operation Details 12:00 Arrived at Swanson 12:10 Held safety meeting w/Supervisor 12:30 On stand-by awaiting Fluid Shot 13:00 Two Fluid Shots were made, 4826' & 4853' 13:20 ~ Tubing pressure at 250 PSI, bled Tubing down to Zero, to do No Flow Test for State 16:45 No Flow Test - satisfactory 17:00 Started R/U, pulled 50' of wire 18:30 Hydro to 1500 PSI -test satisfactory 19:00 RIH w/2.0" GR to 10625', POOH 20:20 RIH w/2.18 RR Plug on X-line R/T to 10297' WL, set Plug, POOH 21:30 OOH, R/D 22:30 Depart Field Tool Cost: 12 hr min $1,830.00 2 7/8" X-line Running Tool $150.00 2.0" Gauge Ring $50.00 Work String Detail:l(1/5" TS) RS, K J, 15' Stem, KJ, OJ, SJ Description of anyNone tools or debris left in the hole: Brief Summary of Made Tag Fill run & set RR Plug Total Work Comleted: Total Hours Worked 12 Total Tool Cost $ 200.00 Total Hour Cost $ 1,830.00 Well Downtime Hr. Ticket # · Daily Cost: P-9730 I $ 2,030.00 H2S PPM Day # :1 3 Cumulative Cost:I $ 3,110.00 Wire Test Approved by: Russell Grainger Code: AFE # 149641 UNQr .AL ALASKA RESOUI ' ;ES WELL SERVICE REPORT Date: Wireline Company: Work Being Done: Present Operations: Supervisor: Wireline Unit Number: Zero Wireline at: Minimum Tubing ID: 8/17/20Ol (Fluid Level) Pollard Wireline Inc. Shoot Fluid Level Complete N/A Tubin 9 Han~ler N/A Well Number: Location: AFE# / Charge Code: Wireline Crew: Total Wireline Miles: Max Depth (KB): Well KB: Max Tool OD: ii SCU 13-34 Swanson River AFE # 149839 F. Pollard N/A N/A N/A N/A Time Operation Details 08:00 Arrive in Field to shoot Fluid Level 08:15 Safety meeting, stand-by for State Man to witness Shoot 11:00 Shoot Fluid Level on Tubing at 4032' (2 shots) 11:20 Swab to Casing, shoot 2 shots @ 4864' 11:40 R/D, test passed 12:00 Leave Field Tool Cost: 6 hr rain $540.00 Work String Detail: IN/A Description of any None tools or debris left in the hole: Brief Summary of Shoot Fluid Level on Casing & Tubing Total Work Casing - 4864' Comleted: Tubinc.:,l - 4032' Total Hours Worked 6 Total Tool Cost N/A Total Hour Cost $ 540.00 Well Downtime Hr. Ticket Daily Cost: N/A P-9735 540.00 Day # :1 1 Cumulative Cost:I $ 540.00 H2S PPM N/A Wire Test N/A Approved by: Robert Wadley Code: AFE # 149839 Unocal Corporation P.O. Box 196247 Anchorage, AK 99501 Telephone (907) 263-7660 UNOCAL Dan Williamson Drilling Manager 9/14/01 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Attn: Re: Commissioner Julie Heusser Subsequent Well Work Report; SCU 13-34 Workover Swanson River Field, Alaska Dear Commissioner Heusser: Unocal Alaska Resources hereby submits its subsequent report of wellwork operations for the subject well. Please find enclosed a Well Completion Report (Form 407), a Workover Summary Report and an updated wellbore schematic. If you have any questions or require additional information, please contact Bill Penrose at 258-3446. Drilling Manager ORIGINAL · ( STATE OF ALASKA ' ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL: X GAS: SUSPENDED: ABANDONED: SERVICE: 2. Name of Operator 7. Permit Number Unocal Alaska Resources 171-021 3. Address 8. APl Number 909 W. 9th Avenue, P.O. Box 196247, Anchorage, AK 99519-6247 50- 133-20231 4. Location of well at surface '" - ~- 9. Unit or Lease Name X: 346163, Y: 348600~,,r.~c~ Soldotna Creek Unit At Top Producing Interval (10280' MD top of Hemlock) ,,_'~ 10. Well Number ; SOU #13-34 At Total Depth 10,960' MD i~'~ 11. Field and Pool ,.-.._ X: 348600, Y: 2477348 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Swanson River Field/Hemlock & Tyonek G 16.5' KBI A-028990 12. Date Spudded8/21/71 13. Date T.D. Reached ] 14. Date Comp., Susp. or Aband. ] 15. Water Depth, if ofshore ] 16. No. of Completions12/14/71 12/23/71 NA feet MS L 1 17. Total Depth (MD+TVD)11551, MD/10828' TVD 18. Plug Back Depth (MD+TVD)11503, MD/10781' TVD I 19' Directi°nal Survey I 20' Depth where SSSV Setyes: x No: NA feet MD I21' Thickness °f Permafr°stNA 22. Type Electric or Other Logs Run None during workover 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 18" 16.5' 70' 0 10-3/4" 40.5# K-55 16.5' 3,063' 12-1/4" Cmtd to surface 0 7" 23, 26,29# N-80 16.5' 10,491' 8-1/2" ~700 sx in 2 stages 0 5" 18# N-80 10,283' 11,549' 6" 175 sx 0 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET '(MD) PACKER SET (MD) 2-7/8" 10,311' 10,311' 11,213' - 11,233' MD / 10,500' - 10,519'TVD (G-zone) 2-3/8" 11,443' 11,331' and 11,406' 11,290' - 11,302' MD/10,575' - 10,587'TVD (H1) 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 11,310' - 11,328' MD/10,594' - 10,612'TVD (H1) DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 11,341'- 11,352' MD/10,624'- 10,635'TVD (H2) 11,362'- 11,381' MD/10,645'- 10,663'TVD (H3) 11,381' - 11,400' MD / 10,663' - 10,682'TVD (H4) 11,414'- 11,445' MD/10,695'- 10,725'TVD (H5) 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) N/A I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO I TEST PERIOD => 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 water. Submit core Chips. None S£P g Z00 ,Alaska OiJ & Gas Cons. Commissio¢ Anchorage __ Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate ORIGINAL GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and lime of each phase. S -p 2001 Alask~ ©il & Gas Coos. Commission A~lchorage 31. LIST OF ATTAOHMENTS Wellbore schematic, Daily Summary of Rig Operations 32. I hereby r..~ify that the foregoing is true and correct to the best of my knowledge Signed ~ ~A,~_~ Title Drilling Manager __Date ~, '"' /~, ~" ~)/ Form 10-407 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 space 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 productin intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- lng 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". ORIGINAL Unocal Alaska Drilling Workover Summary Report SCU 13-34 7/31101 to 8/11101 7/31/01 Accept H&R Rig #9 at 24:00 hrs, 7/30/01. Test surface equip and set bleed tank. Bleed down annulus and tbg. Monitor well - well dead. Install BPV and N/D tree. N/U BOPE and test to 300/3,000 psi - OK. 8/1/01 Pump 3% KCI down tbg. Pull BPV, install 2-way check. Test blind rams and additional valves. Pump down annulus and R/U to RIH w/tbg cutter. Pull tbg hanger free and RIH w/severing charge. Fire chemical cutter at 11,240'. Pump KCI brine down tbg and annulus. Work tbg free and pump brine down tbg. Monitor well, then POH, laying down tbg. 8/2/01 Finish POH, laying down tbg. P/U overshot fishing assy and RIH, picking up drill pipe. 8/3/01 Finish RIH w/fishing assy, picking up drill pipe. Engage tubing stub and commence jarring. 8/4/01 Continue working fish w/o apparent success. Rotate to back off fish. POH standing back drill pipe. L/D fish consisting of tbg stub, pkr, 'S' nipple, 1 jt tbg, blast joint and top half of safety joint. M/U and RIH w/ 7" csg scraper and overshot wireline re-entry guide. Set re-entry guide on bottom half of safety joint. 8/5/01 POH to 8,794'. Set storm packer. N/D BOP stack, N/U tbg bowl adapter and replace leaking wing valve. N/U BOP stack and shell test to 1,500 psi. Pressure test flange breaks to 3,000 psi. Retrieve storm pkr and POH laying down 3-1/2" drill pipe. 8/6/01 L/D BHA and drill pipe from derrick. P/U and RIH w/completion assy. Pkr tagged up at 5,656'. Could not work past. 8/7/01 POH w/completion assy, standing tbg back in derrick. P/U Baker Model 'D' pkr and RIH on tbg. Tag up at 6,257'. Could not work past. POOH and test BOPE. 8/8/01 Finish BOP test. P/U 5-3/4" tapered mill and RIH, picking up 3-1/2" drill pipe. Run past previously encountered tight spots but tag up on DV collar at 6,636'. Lightly ream on DV. 8/9/01 8/10/01 8/11/01 8/12/01 POOH, standing back drill pipe. Change tools from 3-1/2" DP to 2-7/8" tbg. P/U production pkr and run on 2-7/8" tbg. Entered top of 5" liner at 10,283' w/packer. Packer prematurely set at 10,317', 34' into packer. Depth acceptable. Set packer w/2,000 psi and sheared releasing pin. POOH and L/D packer running assy. M/U and RIH w/2-7/8" completion assy. Tag up on packer, space out and set tubing hanger with 16k lbs of tension on the tubing. L/D 3- 1/2" drill pipe from derrick. Finish L/D 3-1/2" drill pipe. Set BPV, N/D BOPE, N/U tree. Test tree and flange to 5,000 psi- OK. Clean mud pits. Released rig at 1600 hrs, 8/11/01 MIRU slickline unit. Remove BPV, run gauge ring to check for obstructions - none found. Run 1-11/16' dummy gun. Tag fill at 11,311'. RDMO. 8/14/01 8/15/01 8/16/01 8/17/01 8/18/01 8/19/01 8/20/01 MIRU wireline unit. Run GR/CCL, tag fill at 11,315'. POH. M/U 1-11/16" Gun #1. RIH, tie in and perforate 11,225 - 11,230'. POH, all shots fired. M/U and RIH wi Gun #2, then Gun #3. Neither would pass 8,746'. Pump 20 bbls base oil down tbg. R/U slickline and RIH w/2.35" gauge ring. Encounter obstruction at 8,937'. Drive down to 10,137'. POH w/slickline. Pump 20 bbls base oil down tbg. Run 2.14" blind box to 10,168', POH. Run 1-11/16" dummy gun to 11,302'. POH and RDMO. MIRU wireline. M/U and RIH w/re-run Gun #2. Tie in and perforate 11,220' - 11,225'. POH, all shots fired. M/U and RIH w/re-run Gun #3. Tie in and perforate 11,210' - 11,220'. POH, all shots fired. Run gauge ring to check for obstructions - none found. RDMO wireline. Shoot fluid level at 3,840'. Shot fluid levels for AOGCC inspector Lou Grimaldi. MIRU slickline and set plug in R- nipple at 10,280'. POH and RDMO slickline. MIRU rod running equipment. Remove tree, install flow cross, valves and rod BOPE. Pump 50 bbls base oil down tbg. Tbg on vacuum. Continue R/U to run rods. M/U rod pumping BHA and RIH on rod string. Finish running rod pumping completion. Space out, close rod BOPE, secure well for later installation of pumping unit. 8/21/01 RDMO rod running equipment and dress location. UNOCALe APl# 50-133-20231-00 Orig. RKB = 16.5' ~ctual Completiol~ Swanson River Field Soldotna Creek Unit Well No. 13-34 Completed 8/10/01 Rods Ran 8/20/01 Casing & Tubing Size Wt Grade- ID To~ Btm 18" Surf 70' 10 3A" 40.5 K-55 10.050 Surf 3063' 7" 23 N-80 6.366 Surf 2537' 7" 26 N-80 6.276 2537' 4343' 7" 29 N-80 6.184 4343 10,491' Liner 5- 118 IN-80 I 4.276 I 10,283' t11,549' Tubing 2-'A" 16.4 IN-80 I 2.441 I 14.70' 110,314' JEWELRY DETAIL Depth NO. Top Btm Length ID OD Item 14.70' 16.50' 0.63' 2.441 - Seaboard Intemational Tension Hanger Polish Rod (spaced out 7' above stuffing box w/ pump 2.22' 2.11' 37.88' 35.77' 1.500 off btm). 1.0 1" EL Sucker Rod, w/Slimhole Class T coupling w/(3) 2.25'' A 38' 3,057' 3,019.00' 2.025 R&M Stealth XL AF Rod Guides per rod .88 7/8" EL Sucker Rod, w/Slimhole Class T coupling w/(3) 3,057' 3,984' 927.00' 1.812 2.25" R&M Stealth XL AF Rod Guides per rod .88 7/8" EL Sucker Rod, w/Slimhole Class T coupling w/(12) 3,984' 6,590' 2,606.00' 1.812 2.25" R&M Stealth XL AF Rod Guides per rod .75 3/4" EL Sucker Rod, w/Slimhole Class T coupling w/(3) 6,590' 10,115' 3,525.00' 1.625 2.25" R&M Stealth XL AF Rod Guides per rod 2.15 1-3/4" RXBC Dbl valve Pump w/Dual Seating Cups w/ B 10,115' 10,159' 43.71' 2.34 Stabilizer Bar. C 10,159' 10,218' 59.46' 1.28 1.665 1-1/4" (1.660" OD) 1-1/4" NPT B x P w/ported bull nose 1 10,162' 10,165' 2.51' 2.28 3.062 Cup Type Seating Nipple, 2-7/8" w/XO's to Butt 2 10,165' 10,171' 6.10' 2.441 2.875 Pup Joint, 6' x 2-7/8", 6.4#, N-80, Butt 3 10,171' 10,175' 4.15' 2.323 3.500 Ported Sub, 2-7/8", 7.2#, Butt BxP 4 10,175' 10,299' 124.00' 2.441 2.875 4 Joints of 2-7/8", 6.4#, L-80, Butt tbg 5 10,301' 10,302' 1.17' 2.188 3.500 Otis "R" Profile nipple, 2.188" w/Butt BxP w/Plug. 6 10,302' 10,308' 6.05' 2.441 2.875 Pup Joint, 6' x 2-7/8", 6.4#, N-80, Butt 7 10,308' 10,313' 4.15' 2.323 3.500 Ported Sub, 2-7/8", 7.2#, Butt BxP 8 10,313' 10,314' 0.78' 1.96 3.430 Baker Model "E" Anchor Latch w/o seals 9 10,314' 10,317' 2.78' 2.00 Baker Model "D", 32-26, Perm Packer. '] G-Zone H1 '] H2 '] H3 '] H4 PBTD = 11,503' TD = 11,551' MAX HOLE ANGLE = 32 deg. @ 7972' PERFORATION HISTORY Intervbl Zone Top Btm Ant Cona~nts G-zone 11,213' 11,233' 20' Perf'd 8/16/01 H1 11,290' 11,302' 12' Pcffd 12/71 HI 11,310' 11,328' 18' Pen°d 12/71 H2 11,341' 11,352' 11' Pen°d 12/71 H3 11,362' 11,381' 19' Pen°d 12/71 H4 11,381' 11,400' 19' Pen°d 12/71 H5 11,414' 11,445' 31' Pen°d 12/71 SCU 13-34 Current dwg 8-10-01 DRAWN BY: slt REVISED: 9/10/01 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Julia Heusser, DATE: Chairman ~ ~,~~~ Tom Maunder, P. I. Supervisor THRU: FROM: Lou Grimaldi, SUBJECT: Petroleum Inspector August 18, 2001 No-Flow Test Unocal SCU13-34 McArthur River Field TBU PTD 171,021, NON-CONFIDENTIAL Friday, August 17.., 2001' I witnessed No-Flow verification on UNOCAL's Soldotna Creek Unit #13-34 in the Swanson River Field. I arrived to find the wireline crew rigged up and ready to run an R plug in the down hole seating nipple. The wells tubing and annulus were both on vacuum. Fluid levels were shot and determined fluid to be at approximately 4000' in the tubing and 4800' in the annulus, The difference was most likely due to the fact that diesel had been pumped in the tubing to try to clear perforating debris that had been left in the hole earlier. I observed the well in this condition for approximately three hours. I explained to Bob Wadley (Unocal rep.) that if the wells conditions changed (pressure buildup) the CommissiOn should be notified immediately. The well exhibited inability to flow to surface unassisted and I recommend it be granted No-Flow status. SUMMARY: I witnessed No-Flow verification on UNOCAL's SCU 13-34 in the Swanson River Field. ,NON-CONFIDENTIAL Attachment: None No-Flow UNOCAL SCU 13-34 8-17-01 LG.doc SCU 32-8 Surface Production Set-Up Subject: SCU 32-8 Surface Production Set-Up Date: Tue, 7 Aug 2001 14:49:05-0800 From: "Bill Penrose" <bi!!@fairweather.com> To: 'q'om Maunder $E-mail$" <tom_maunder@admin.state.ak. us> Tom, The attached diagrams should answer the questions you asked earlier. The second page of the attachment shows the proposed surface production set up for SCU 13-34, the well we're on now. The production set-up for SCU 32-8 will be identical. The item labelled #5 is the surface safety valve. You can see that it resides on the gas side of the production stream where the gas is being produced from the annulus. The item labelled #10 is the rupture disk set for 1500 psi. You can see that a blockage such as a shut valve occuring downstream will rupture the disk and send the pumped oil into recyle. Regards, Bill Name: 13-34 Tree.doc 3-34 Tree.doc T¥1~: WINWORD Fil~ (applicationlmsword) Encoding: base64 lofl 8/7/01 3:00 PM Proposed Bal~ Valve ~2 2-9,q 6 x 24/!t6' 1;3 ~7 SCU 13-34 Tree Current , , 2. ~ 11" 5k x 2-1/16" 5k 5000 R-46 18431-T 6-3/8" l~. P.H. 121513 ,4.,' Cantata Ty~FC 2-~~ ~00 69~32-~6-4 5. "wKM Modal ~L~ 2-1/2' 50OO ~36-1 6~ Cnnn~' Tyi~F, 2-1/16" 5000 692331-16-1 "?. .Camermt. TypeF , 2-!ll,.ff'' 5000 32901-'1"0-1 .... " 8. w-gM Ammal 2-1fl6" 50O0 z 535~8 9. Cammxm Type F 2_'1/16,, ~ ,, 32901-10-1 ....... 10. Canmrmn , TypeF 2,-1!!6~ ~ 5000 32901-10-1. ,, 11. Rodm~ rh~ 2" .......... "~00 40~4~, ..... 12; ~ r~, 2~ , .... sooo , , Comments I2-1/2~ Cosasco BP¥ No neck oil Hanger Tbg .... Cag Hngr test to 3000 psi 5 6 17' 12 9 10 11 Re: [Fwd: Vafience For Single Gate Ram on Swanso; ~ ~,,er SCU 13-34] Subject: Re: [Fwd: Varience For Single Gate Ram on Swanson River SCU 13-34] Date: Wed, 01 Aug 2001 12:10:32 -0800 From: Jane Williamson <Jane_Williamson~admin.state. ak.us> Organization: Alaska Oil & Gas Conservation Commission To: Thomas E Maunder <tom_maunder~admin.state. ak.us> Subject: Varience For Single Gate Ram on Swanson River SCU 13-34 Date: Tue, 31 Jul 2001 23:53:38 -0700 From: "Williamson, Dan R" <williamsond@unocal.com> To: "'Williamson, Jane AOGCC'" <jane_williamson~admin.state.ak.us> CC: "Byme, Don S" <bymeds~Orion. Unocal.com>, "Grainger, Russell L-Contract" <Graingerr~Ofion. Unocal.com>, "Williamson, Dan R" <williamsond~Orion. Unocal.com>, "Tyler, Steve L.-Contract" <tylersl~Orion. Unocal.com> On 7/31/01 at 10:30 PM, I had a phone conversation with you requesting a variance to the AOGCC regulations concerning the requirement for an additional set of 2 3/8" rams to cover a length of approximately 1100' of tubing and drill pipe that will be pulled and run in Swanson River 13-34 WO. Contingencies to Allow Granting the Variance * The well is a certified "no flow producer". * We are using 3% KCL as the kill fluid for this well which will overbalance it by several hundred PSI. * There is also'an annular preventer on the well and it will be closely monitored on the trip tank. Based on the reason above you granted a verbal variance to this rule. again thank you for your cooperation in this matter. 1 ofl $/1/01 1:37 PM Dan Williamson Drilling Manager Unocal Corporation P.O. Box 196247 Anchorage, AK 99501 Telephone (907) 263-7660 UNOCALe) JUL 2, $ 00/ Alaska Oil & Gas Cons 7/25/01 Anchora(~e' Commission Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Attn: Re: Commissioner Julie Heusser Application for Sundry Approval; SCU 32-8 Workover Swanson River Field, Alaska Dear Commissioner Heusser: Unocal Alaska Resources hereby submits an Application for Sundry Approval for its plan to convert the existing gas lift completion in Well SCU 32-8 to a rod pump completion. Previously, we had planned to similarly convert Well SCU 33A-8. However, that well was found to contain collapsed casing and tubing and will be plugged and abandoned. SCU 32-8 is proposed as a substitute. SCU 32-8 currently produces 205 BOPD and 15 BWPD on gas lift and the production rate is declining rapidly. The proposed workover will consist of pulling the old completion, running new tubing with appropriate rod pumping jewelry and completing the well with a rod pump and rods. Because this well will not flow unassisted, Unocal requests approval to re-complete this well without a surface safety valve. For this same reason, we also request approval to test BOPE to a maximum of 3,000 psi. Please find enclosed an Application for Sundry Approval (Form 403), a summary workover procedure and a wellbore schematic. If you have any questions or require additional information, please contact Bill Penrose at 250-3113. Sincerely, Dan Williamson Drilling Manager RECEIVED JUL 2 5 Z001 Alaska Oil & Gas Cons. Commission Anchorage AOGCC Sundry Cover Ltr ORIGINAL Bill Penrose STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 1. Type of Request: . o [ ] Abandon [ ] Alter Casing [ ] Change Approved Program [ ] Suspend [ ] Plugging [ ] Repair Well [X] Pull Tubing [ ] Operation Shutdown [ ] Re- Enter Suspended Well o Name of Operator UNOCAL ALASKA RESOURCES 5. Type of well: IX] Development [ ] Exploratory [ ] Stratigraphic [ ] Service 12. Address 909 W. 9th Avenue, P.O. Box 196247, Anchorage, AK 99519-6247 Location of well at surface *// ,2' ~ 1850' FNL, 1970' FEL, Sec. 8, T7N, R9W, SM At top of productive interval Straight Hole At effective depth Straight Hole At total depth Straight Hole Present well condition summary ! Total depth: measured 10,828 feet*/ true vertical 10,828 feet Effective depth: measured 10,631 feet true vertical 10,631 feet Casing Length Size Structural Conductor 28' 22" Surface 2,995' 13-3/8" Intermediate P rod uction 10,836' 6-5/8" Liner ] Time Extension [ ] Perforate ] Vadance [X] Other ] Stimulate * Convert well to rod pump 6. Datum Elevation (DF or KB) 15' AGL 7. Unit or Property Name Soldotna Creek Unit 8. Well Number 32-8 9. Permit Number 160-045 10. APl Number 50-133-10118-00 11. Field and Pool Swanson River: Hemlock Plugs (measured) None Junk (measured) None Cemented MD TVD Cmtd f/surf to 28' 28' 28' Cmtd w/1900 sx in 2 stages 3,014' 3,014' Cmtd w/1400 sx in 2 stages 10,828' 10,828' Perforation depth: measured True vertical Tubing (size, grade and measured depth) Packers and SSSV (type and measured depth) 10,506' - 10,676' (8 intervals) 10,506' - 10,676' (8 intervals) 2-7/8", 6.5#, N-80 at 10,507' Baker 'FH' Packer, 2-7/8" x 6-6/8" RECEIVED JUL 2, 5 2001 Alaska 0il & Gas Cons. Commission Anchorage 13. Attachments [X] Description of Sumary Proposal 14. Estimated date for commencing operation 7/31/2001 16. If proposal was verbally approved Name of approver N/A Date Approved Contact Engineer Name/Number'. Bill Penrose, 250-3113 ] Detailed Operations Program 15. [ ] BOP Sketch Status of well classification as: IX] Oil [ ] Gas Service [ ] Suspended Prepared By Name/Number: Bill Penrose, 250-3113 17. I hereby certify that the foregoing is true and correct to the best of my knowledge ,,--.Signed / ~r-c,~ o,~¢. ¢-. ~.~.,~,~ so,,~ , ~~~ Title ~'~'~ ~~ Date Commission Use Only Conditions of Approval: Notify Commission so representative ma_y,witness '~~~:~,t .~%-~ Plug integrity ~ BOP Test~ Location Cleararfce Mechanical Integrity Test~ Subsequent form required 10- Approved by order of the Commission Form 10-403 Rev. 06/15/88 ORIGINAL SIGNED BY D Taylor Seamount Commissioner IApproval No. 2,,('-~1- ,.9,11,-, SulJrn~t4 n-Triplicate ORIGINAL Unocal Alaska Business Unit Swanson River Field Well SCU 32-8 AFE # Prepared by: WJP Date: 7/01 Estimate for Non-drilling AFEs (Cap Recomp, SWR, Abandonment) UNOCAL ) No. Preliminary Procedure Time CUM CUM Estimate Time Time (Hours) (Hours) (Days) Prep Well For Workover Test Wellhead Workover 1 MIRU Workover Rig 0 0 0.0 2 Fill Tbg and Annulus w/Base Oil, Stabilize Well 12 12 0.5 3 Set BPV, N/D Tree, N/U BOPE and Test 18 18 0.8 4 M/U Landing Joint, Pull Tbg Hgr to Floor, Circulate Well ~ 21 0.9 5 POH and L/D Tbg and Jewelry (10,507') 16 37 1.5 6 P/U and RIH w/2-7/8" Completion to 10,465' 12 49 2.0 7Set Pkr, Land Tubing 4 53 2.2 8 Set BPV, N/D BOPE, N/U Tree, Test Tree 12 65 2.7 9 RDMO Workover Rig 0 65 2.7 Post-Rig Work Complete with Pumping Unit, Downhole Pump and Rods I Subtotal (Days) 2.71 Loss/Trble Time (11% ) 0.30 Total Project Days 3.01 Note: Loss, Trouble, Unplanned is based on 11%. Also, the risked troubled costs were included in the AFE costs. SCU 32-8 AFE Est Page 1 of 1 7/25/2001 Well- scu 32-8 Spud Date: 1/3/61 ~riginal RKB: 22' '3p of Hemlock:10,506'MD Max, Hole Angle: Arco Alaska Inc. - Swanson River Reid APl#: 133-10118-00 Well Type: Producer Completion Date: 2/22/61 Last Workover: 9/85 Hanger Type Shaffer Hanger: Shaffer 3° Angle @Hemlock: All Depths are RKB MD to Top of Equipment. Jewelry 1 23' 2 39' 3 1672' 4 3005' 5 3956' 6 4750' 7 5329' 8 10,422' 9 10,465' 10 10,503' 11 10,505' 12 10,507' Tubing Hanger Fatigue Nipple Camco MM Mandrel w/Dummy Camco MM Mandrel w/Dummy Camco MM Mandrel w/Dummy Camco MM Mandrel w/Dummy Camco MM Mandrel w/Dummy Camco MM Mandrel w/Dummy Baker "FH" Packer 2 7/8" x 6 5/8" Otis "S" Nipple Tubing Pup Baker Shear Sub 0 H1 H2 H3 H4,5 10 11 12 Minimum ID: 2.441" ~ 10.503 (Otis "S" NioDle~ . . ~ Casing and Tubing Size Weight ~ Bottom 22" 13-3/8" 6-5/8" 2 7/8" 0 54.5# 0 28# P-110 0 24# N-80 115' 24# P-110 6477' 28# P-110 10,037' 6.5# N-80 0 28' 3014' 115' 6477' 10,037' 10,828' 10,507" Perforation Data Interval Zone 0,506'-10,516' H1 0,516'-10,526' 0,526'-10,532 0,545'-10,572' H2 0,576'-10,580' 0,585'-10,600' H3 0,603'-10,611' 0,617'-10,676' H4,5 FT SPF 10' 4 10' 1.2 6' 12 27' 12 · 4' 4 15' 12 9' 4 59' 4 Description Sudace Casing Production Casing. Liner Tubing Date Comments 1985 SQZ. '70,'85 Reped 1985 Ped '70,'85 Repeal 1985 SQZ. '70,'85 Repeal 1985 SQZ. 1985 SQZ. PBTD = 10,631' TD = 10,828' Well SCU 32-8 By: JLB 10/23/89 STATE OF ALASKA (~ ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 1. Type of Request . . . [ ]Abandon [ ]Suspend [ ] raging [ ] Alter Casing [ ] Repair Well ] Pull Tubing [ ] Change ~ Program [ ] Operation Shuldown ] Re- Enter Suspended Well Name of Operator UNOCAL ALASKA RESOURCES Address 909 W. 9th Avenue, P.O. Box 196247, Anchorage, AK 99519-6247 Location of well at surface 67' FSL, 1889' FEL, Sec. 33, T8N, R9W, SM At top of productive interval At effective depth At total depth 1794' FSL, 630' FWL, Sec. 32, T8N, R9W, SM 12. Present well condition summary 5. Type of well: [X] Development [ ] Exploratory [ ] Stratigraphic [ ] Service ] Time Extension [ ] Perforate ] Variance [X] Other* ] Stimulate *Convert well to rod pump 6. Datum Elevation (DF or KB) 17' RKB 7. Unit or Property Name Soldotna Creek Unit 8. Well Number 13-34 9. Permit Number 10. APl Number 50-133-20231 11. Field and Pool Sw~l~l~J~;~r'~onek G Total depth: measured 11,551 feet true vertical 10,828 feet Effective depth: measured 11,503 feet true vertical 10,781 feet Casing Length Size Structural N/A Conductor 53' 18" S u rface 3,046' 10-3/4" Intermediate N/A production 10,474' 7" Liner 1,266' 5" Plugs (measured) Junk (measured) None JUN 0 1 Z001 None Alaska Oil & Gas Cons. Commission Cemented A~ TVD 70' 70' 3,063' to surface 3,063' 3,063' 700 sx in 2 stages 10,491' 9,806' 175 sx 11,549' 10,826' Perforation depth: measured: (11,290'-11,302'), (11,310'-11,328'), (11,341 '-11,352'), (11,362'-11,381'), (11,381'-11,400') and (11,414'-11,445') true vertical: (10,575'-10,587'), (10,594'-10,611 '), (10,633'-10,644'), (10,645'-10,663'), (10,663'-10,682') and (10,695'-10,725') Tubing (size, grade and measured depth) 2-7~8", N-80 surf to 10,208' and 2-3~8", N-80 fl 10,208' to 11,443' Packers and SSSV (type and measured depth) 5" Baker Model FH retrievable packers at 11,250', 11,331' and 11,406' '13. Attachments [X] Description of Sumary Proposal [ ] Detailed Operations Program [X] BOP Sketch 14. Estimated date for commencing operation I 15, Status of well Classification as: 16'.' If proposal was verbally approved ! [X] Oil [ ] Gas 6/15/01 [ ] Suspended 'i7. Name of approver Date Approved Contact Engineer Name/Number: Bill Penrose, 258-3446 ! h. eret~?~rtify that'~e fo/~g is true and cOrrect to the be/lst of~y kno~l~ge Service Prepared By Name/Number: Bill Pontese, 258-3446 Commission ~se d~ly Conditions of Approval: Notify C'ommission so representative mayj~vitness ~OI~IL~ ~%"(. ~(C)~,~.- Plug integrity ~ BOP Test ~, Locatibn Clearance [ _ ~ Mechanical Integrity Test Subsequent form required 10- Approved by order of the Commission ORIGINAL SIGNED t3 Commissioner Form 10-403 Rev. 06/15t88 D T~yluf Seamuun'.. Date ~"'/" O/ IApproval No. ¢~'~;:i~7;-~ ,7,¢¢/' 8ubmlt,(n Tr~iicat~ ORIGINAL ~,od Pumped Wells at Swanson R. Subject: Rod Pumped Wells at Swanson R. Date: Fri, 8 Jun 2001 15:53:33 -0800 From: "Bill Penrose" <bill@fairweather. com> To: "Tom Maunder $E-mail$" <tom_maunder@admin.state.ak.us> Tom, Per your e-message of 6/1/01, attached is a diagram showing the site layout, work platform and BOP stack for the planned rod pump completions. The BOPs are manually operated and have no accumulator system. This is the normal setup for rod pump well-work operations (since the wells won't flow) and the same system as was permitted for running the rod pump completion on Platform Dillon. The crane operation proposed for running the rods is also the same as that used for the Dillon operation. Please call or drop a line with any questions or comments. Regards, Bill ~__~SCU 13-34 Site & BOP Dwg.doc Name: SCU 13-34 Site & BOP Dwg.doc t Type: WINWORD File (application/msword)I ~E_~c°ding:~ ..~ ... ba_~sw~e_~ '~~J 1 of 1 6/11/01 8:50 AM SCU 13-34 BOP Arrangment While running Rods Rod Table Riser Pipe to 3' above deck od work platform floor Flow Tee -% Manual Variable Ram (0 to 1-1/2") 1500 psi WP BOPE From Pump ,,~ I 47.00" 85.5" 7.125' ?o5" I 9.5" Choke Site Plan Work Platform Swanson River SCU 13-34 Rod Pump Conversion Summary 1. Slickline tubing clean out with brush. Change-out GLV's to dummies. Pressure test tubing. 2. E/line perforate proposed G-zone 11,213'-11,233' through 2-3/8" robing. 3. Set retrievable bridge plug above G-zone perforations. ~ 4. Tubing punch holes in 2-3/8" tubing, 20'+ below 2-7/8" x 2-3/8" XO. 5. Pull retrievable bridge plug. . Utilizing a 50-ton crane. Run Gas Anchor Dip Tube, Anchor Packer, 1-1/2" Pump and rods with guides. Set Anchor Packer in 2-3/8" tubing, above tubing punched holes. RECEIVED JUN 0 ~l ~'001 Alaska, Oil & Gas Cons. Commission Well- soU/ 13-34 Spud Date~'-8/71* Original RKB: 16.5' Top of Hemiock:11,288'MO Alaska Inc.- Swanson APl#: 133-20231-00 Completion Date: 12/71 Hanger Type: Shaffer Max. Hole Angle: '32° ;Id Well Type' Producer Last Workover: Hanger: (6"x3-1/2" EUE 8rd) Angle @Hemlock: 1'4o All Depths are RKB MD to Top of Equipment. 10 L. Jewelry 1 2042' 2 3679' 3 4877' 4 5794' 5 6430' 6 6913' 7 7303' 8 7631' 9 10.208' , .,~ 10 11,216' 11 11.250' 13 11.287' 14 11.307' 15 11,308' 16 11,329' 17 11,331' 18 11,337' 19 11,338' 20 11,403' 21 11,406' 22 11,411' 23 11,443' 2-7/8" Camco MM GLM w/x-over 2-7/8" Camco MM GLM w/x-over 2-7/8" Camco MM GLM w/x-over 2-7/8" Camco MM GLM w/x-over 2-7/8" Camco MM GLM w/x-over 2-7/8" Camco MM GLM w/x-over 2-7/8" camco MM GLM w/x-over 2-7/8" Camco MM GLM w/x-over to 31/2" Butlmss both ends to 31/2" Buttress both ends to 31/2" Buttress both ends to 31/2" Buttress both ends to 31/2" Buttress both ends to 31/2" Buttress both ends to 31/2" Buttress both ends to 31/2" Buttress both ends X-Over 3-112' Buttress x 2-7/8" EUE 8rd (Fish-PS Plug) X-C~/er 2-7/8" EUE 8rd x 2-3/8" EUE 8rd Camco "C" Sleeve 2-3/8" Open Upward Baker "FH" Packer 2-3/8" x 5" 18# Offs "S" NI;pple 2-3/8' Position ~3.. Baker Blast Joint 2-3/8" ID 2.875" Brown "CC" Safety.Joint Baker Blast Joint 2-3/8" ID 2.875" Camco 'C" Sleeve 2-3/8" Open Upward Baker "FH" Packer 2..318" x 5" 18# Offs "S" Nipple 2-3/8" Position #2 Baker Blast Joint 2-3/8' ID 2.875" Camco "C" Sleeve 2-3/8" Open Upward Baker "FH" Packer 2-3/8" x 5" 18~ Camco "D" Nipple 2-3/8" Tubing Tall H1 H1 H2 H3,4 11 13 14 15 , 16 17 18 ¸19 2] 21 22 Casing and Tubing Size .. Weight Grade Top Bottom Description 18" 10-3/4" 40.5~ K-55 7' 23~ N-80 . 7" 26~ N-80 7" 29~ N-80 5" 18~ N-80 2 -7/8' 6.5t N-80 2-3/8" 4.3~ N-80 Perforation Data 0 70' Strucfure Casing 0 3063' Surface Casing 0 2537' Production Casing 2537' 4343' 4343' 10,491' 10,283' 11.549' Uner · 0 10,208' Tubing 11,208' 11,443" Tubing Interval Zone FT SPF 11.290'-11,302' H1 12 4 11,310'-11,328' H1 18 4 11,341'-11,352' H2 11 4 11,362'-11,381' H3 19 4 11,381 '-11,400' H4 19 4 11,414'-11,445' H5 31 4 12/71 Comments Peff Tubing 11,314'-11,324' H5 PBTD = TD = 11,503' 11,551' Well SCU13-34 By: JLB 1/30~2 SCIJ 13-34 BOP Arranqmer~t Whi~e runninq Rods Site Plan Work Plattbrm SCU i 3-34 Rod Pump Procedure 4~3,-01 12 4/3/01 Unocal Corporation P.O. Box 196247 Anchorage, AK 99501 Telephone (907) 263-7677 UNOCAL ) RECEIVED JUN 0 1 ZOO1 Alaska 0il & Gas Cons. Commission Dan R. Williamson Drilling Manager Friday, June 01, 2001 Ms. Julie Heusser, Commissioner AOGCC 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 Application for Sundry Approval; SCU 13-34 Non-Rig Rod Pump Re-Completion, Swanson River Field, Alaska Dear Commissioner Heusser, Unocal Alaska Resources hereby submits an Application for Sundry Approval for its plan for a non-rig workover of Well SCU 13-34 to convert it to a rod pump completion. The Commission has already received an Application for Sundry Approval for the rig workover version of this project. While we still request approval of that Application, Unocal proposes to first attempt converting this well to a rod pump completion without a rig in order to evaluate its success. The rods will be run using a 50-ton crane and a dual ram BOP stack. If this non-rig workover option is not successful, the rig option will be utilized. SCU 13-34 is a shut-in, Iow rate Hemlock oil producer. The proposed workover will consist of pulling the old completion, re-perforating the Hemlock, adding perforations in the G-zone and re-competing with a rod pump completion. Because this well will not flow unassisted, Unocal requests approval to re- complete this well with a surface safety valve only on the annulus side where the gas separated downhole will be produced. For this same reason, we also request approval to test BOPE to a maximum of 3,000 psi. The anticipated commencement of this workover is approximately June 15. AOGCC Page 2 June 1,2001 Please find enclosed an Application for Sundry Approval (Form 403), a summary workover procedure and a wellbore schematic. If you have any questions or require additional information, please contact Bill Penrose at 258-3446. Sincerely, UNOCAL ALASKA RESOURCES Dan Williamson Drilling Manager enclosures cc: Bill Penrose Unocal Corporation P.O. Box 196247 Anchorage, AK 99501 Telephone (907) 263-7677 UNOCAL ) JUN Alaska 0ii & Ga~ Cons. Commission Dan R. Williamson Drilling Manager Friday, June 01, 2001 Ms. Julie Heusser, Commissioner AOGCC 333 West 7th AVe., Suite 100 Anchorage, Alaska 99501 Application for Sundry Approval; SCU 13-34 Non-Rig Rod Pump Re-Completion, Swanson River Field, Alaska Dear Commissioner Heusser, Unocal Alaska Resources hereby submits an Application for Sundry Approval for its plan for a non-rig workover of Well SCU 13-34 to convert it to a rod pump completion. The Commission has already received an Application for Sundry Approval for the rig workover version of this project. While we still request approval of that ApPlication, Unocal proposes to first attempt converting this well to a rod pump completion without a rig in order to evaluate its success. The rods will be run using a 50-ton crane and a dual ram BOP stack. If this non-rig workover option is not successful, the rig option will be utilized. SCU 13-34 is a shut-in, Iow rate Hemlock oil producer. The proposed workover will consist of pulling the old completion, re-perforating the Hemlock, adding perforations in the G-zone and re-competing with a rod pump completion. Because this well will not flow unassisted, Unocal requests approval to re- complete this well with a surface safety valve only on the annulus side where the gas separated downhole will be produced. For this same reason, we also request approval to test BOPE to a maximum of 3,000 psi. The anticipated commencement of this workover is approximately June 15. AOGCC Page 2 June 1, 2001 Please find enclosed an Application for Sundry Approval (Form 403), a summary workover procedure and a wellbore schematic. If you have any questions or require additional information, please contact Bill Penrose at 258-3446. Sincerely, UNOCAL ALASKA RESOURCES Dan Williamson Drilling Manager enclosures cc: Bill Penrose RECEIVED JUN 0 AJaska Oil & Gas Cons. Commission UNOCALe Orig. RKB = 16.5' s(VVanson River Field SCU 13-34 Casinq & Tubing Size Wt Grade ID Top Btm 18" Surf 70' 10 %" 40.5 K-55 10.050 Surf 3063' 7" 23 N-80 6.366 Surf 2537' 7" 26 N-80 6.276 2537' 4343' 7" 29 N-80 6.184 4343 10,491' Liner 5" 118 IN-80 I 4.276 I 10,283' I 11,549' Tubing 2-7A'' 16.4 iN-80 12.441 [ 14.70' I 10,314' JEWELRY DETAIL Depth NO. Top Btm Length. ID OD Item 14.70' 16.50' 0.63' 2.441 - Seaboard International Tension Hanger Polish Rod (spaced out 7' above stuffing box w/ pump 2.2 2.11' 37.88' 35.77' 1.500 off btm). 1.0 1" EL Sucker Rod, w/Slimhole Class T coupling w/(3) 2.2 A 38' 3,057' 3,019.00' 2.025 R&M Stealth XL AF Rod Guides per rod .88 7/8" EL Sucker Rod, wi Slimhole Class T coupling w/(3) 3,057' 3,984' 927.00' 1.812 2.25" R&M Stealth ×L AF Rod Guides per rod .88 7/8" EL Sucker Rod, w/Slimhole Class T coupling w/(12) 3,984' 6,590' 2,606.00' 1.812 2.25" R&M Stealth XL AF Rod Guides per rod .75 3/4" EL Sucker Rod, w/Slimhole Class T coupling w/(3) 6,590' 10,115' 3,525.00' 1.625 2.25" R&M Stealth XL AF Rod Guides per rod 2.15 1-3/4" P, XBC Dbl valve Pump w/Dual Seating Cups w/ B 10,115' 10,159' 43.71' 2.34 Stabilizer Bar. C 10,159' 10,218' 59.46' 1.28 1.665 1-1/4" (1.660" OD) 1-1/4" NPT B x P w/ported bull nose 1 10,162' 10,165' 2.51' 2.28 3.062 Cup Type Seating Nipple, 2-7/8" w/XO's to Butt 2 10,165' 10,171' 6.10' 2.441 2.875 Pup Joint, 6' x 2-7/8", 6.4#, N-80, Butt 3 10,171' 10,175' 4.15' 2.323 3.500 Ported Sub, 2-7/8", 7.2#, Butt BxP 4 10,175' 10,299' 124.00' 2.441 2.875 4 Joints of 2-7/8", 6.4#, L-80, Butt tbg 5 10,301' 10,302' 1.17' 2.188 3.500 Otis "R" Profile nipple, 2.188" wi Butt BxP w/Plug. 6 10,302' 10,308' 6.05' 2.441 2.875 Pup Joint, 6' x 2-7/8", 6.4#, N-80, Butt 7 10,308' 10,313' 4.15' 2.323 3.500 Ported Sub, 2-7/8", 7.20, Butt BxP R 'Iff q4q' ~1~ "~4 ~4, ~ ?~' 4 QR ~t .4'~t~ D.,l~m~. K~lh,4~l ,,[~s, A,n~l~. I ~4.~1~ ~a,l~ .... -3 G-Zone H1 '] H2 -] H3 -] H4 PBTD -- 11,150:3'TD - 11,551' MAX HOLE ANGLE = 32 deg. ~ 7972' SCU 13-34 BOPE PERFORATION HISTORY Interval Zone Top Btm Ant Con~ents G-zone 11,213' 11,233' 20' Perfd 8/16/01 H1 11,290' 11,302' 12' Perl'd 12/71 H1 11,310' 11,328' 18' Pcrfd 12/71 H2 11,341' 11,352' 11' Perl'd 12/71 H3 11,362' 11,381' 19' Peffd 12/71 H4 11,381' 11,400' 19' Perf'd 12/71 1-I5 11,414' 11,445' 31' Perl'd 12/71 2 5/7/01 'AL ALASKA RESOUI[ ;ES WELL SERVICE REPORT Date: Wireline Company: Work Being Done: Present Operations: Supervisor: Wireline Unit Number: Zero Wireline at: Minimum Tubin~l ID: 8/17/2001 (Fluid Level) Pollard Wireline Inc. Shoot Fluid Level Complete N/A Tubing Hanger N/A Well Number: Location: AFE# / Charge Code: Wireline Crew: Total Wireline Miles: Max Depth (KB): Well KB: Max Tool OD: scu 13-34 Swanson River AFE # 149839 F. Pollard N/A N/A N/A N/A Time Operation Details 08:00 Arrive in Field to shoot Fluid Level 08:15 Safety meeting, stand-by for State Man to witness Shoot 11:00 Shoot Fluid Level on Tubing at 4032' (2 shots) 11:20 Swab to Casing, shoot 2 shots @ 4864' 11:40 R/D, test passed 12:00 Leave Field Tool Cost: 6 hr min $540.00 Work String Detail: IN/A Description of any None tools or debris left in the hole: Brief Summary of Shoot Fluid Level on Casing & Tubing Total Work Casing - 4864' Comleted: Tubing - 4032' Total Hours Worked 6 Total Tool Cost N/A Total Hour Cost $ 540.00 Well Downtime Hr. Ticket # '1 Daily Cost: $ N/A P-9735 540.00 Day # :1 Cumulative Cost:I $ H2S PPM N/A Wire Test N/A 540.00 Approved by: Robert Wadley Code: AFE # 149839 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 1. Type of Request: [ ]At)andon [ ] Alter Casing [ ] Change Approved Program 2. Name of Operator UNOCAL ALASKA RESOURCES []Suspend [ ] Repair Well [ ] Operation Shutdown 3. Address 909 W. 9th Avenue, P.O. Box 196247, Anchorage, AK 99519-6247 4. Location of well at surface ~'' ,/" ''/ 67' FSL, 1889' FEL, Sec. 33, T8N, R9W, SM At top of productive interval At effective depth i2. At total depth 1794' FSL, 630' FWL, Sec. 32, T8N, R9W, SM Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical [ ] Plugging [ ] Time Extension [X] Perforate IX] Pull Tubing [ ] Variance [X] Other* ] Re- Enter Suspended Well [ ] Stimulate *Con,~wt well to rod pump 5. Type of well: [X] Development [ ] Exploratory [ ] Stratigraphic [ ] Service Alaska 0i7 & ~.o. .... u~ ageC°ns 11,551 feet ~ Plugs (measure) 10,828 feet ~ 11,503 feet Junk (measured) 10,781 feet 6. Datum Elevation (DF or KB) 17' RKB 7. Unit or Property Name Soldotna Creek Unit 8. Well Number 13-34 9. Permit Number 10. APl Number V~ 50-133-20231 ,, 11. Field and Pool Swanson River. Hemlock & Tyonek G None None Casing Length Size Cemented MD TVD Structural N/A Conductor 53' 18" 70' 70' Surface 3,046' 10-3/4" 3,063' to surface 3,063' 3,063' Intermediate N/A Production 10,474' 7" 700 sx in 2 stages 10,491' 9,806' Liner 1,266' 5" 175 sx 11,549' 10,826' Perforation depth: measured: (11,290'-11,302'), (11,310'-11,328'), (11,341'-11,352'), (11,362'-11,381'), (11,381'-11,400') and (11,414'-11,445') true vertical: (10,575'-10,587'), (10,594'-10,611 '), (10,633'-10,644'), (10,645'-10,663'), (10,663'-10,682') and (10,695'-10,725') Tubing (size, grade and measured depth) 2-7/8", N-80 surf to 10,208' and 2-3/8", N-80 f/10,208' to 11,443' Packers and SSSV (type and measured depth) 5" Baker Model FH retrievable packers at 11,250', 11,331' and 11,406' 13. Attachments [X] Description of Sumary Proposal [ ] Detailed Operations Program [ ] BOP Sketch 15. 14. Estimated date for commencing operation 6/28/01 16. If proposal was verbally approved Name of approver Date Approved Status of well classification as: [X] Oil [ ] Gas Service [ ] Suspended Contact Engineer Name/Number: Bill Penrose, 258-3446 ,, 17. I hereby~..'~tify that the foregoJrm is true and correct to the best of my knowledge _ · ..- - v ..... --- Co~n~lissio~ Us/e/_On'ly 7./' conditions 0f Approval: Notify Commission so representative ma[witness '~O(:3E~ ~. ~1~3~ ~~ Plug integrity ~ BOP Test .'~ Location Clearance Mechanical Integrity Test~ Subsequent form required 10- ORIGINAL SIGNED BY Commissioner Approved by order of the Commission r~ -r-,,..,-- r, Form 10403 Rev. 06/15/88 ~, , o,~,~,, ,~=~,~uu~l ' Prepared By Name/Number: Bill Penrose, 258-3446 Date IApproval No. ~'~"')l-lc~J Date ~//f~J Subrn~it'ln 7'riplic~te ORIGINAL Unocal Alaska Business Unit Swanson River Field Well # SCU 13-34 AFE # Prepared by: WJP Date: 3/01 Estimate for Non-drilling AFEs (Cap Recomp, SWR, Abandonment) ii N°. Preliminary Procedure Time CUM CUM Estimate Time Time (Hours) (Hours) (Days) i Pre-Rig Work Test Wellhead Use Slickline to Pull valve ~ GLM ~ 7,631' Circulate 6% KCI Down Tbg, Out Annulus Work#vet 1- MIRU Workover Rig ~.. 72 72 3.0 2 Set BPV, N/D Tree, N/U BOPE and Test 15 87 3.6 ..... 3 M/U Landing Joim and Attempt to Pull Packers Loose 2 89 3.7 4 R/U APRS, Cut 2-7/8" Tbg ~ 10,175', R/D APRS 6 95 4.0 ....... 5 POH and L/D 2-7/8" Tbg and Jewelry (10,175') 15 110 4.6 6 P/U Drill Pipe w/O~,ershot, RIH 20 130 5.4 7 Engage Tbg Stub and Jar Loose Pkrs, PoH and L/D Jewelry ' 8 138 5.8 8 R/U SWS, Make 8 PerfRuns Btwn 11,213' and 11,445', R/D SWS 24 162 6.8 · 9 P/U and RIH w/2-7/8" Completion (10,200') 24 186 7.8 10 Set BPV, N/D BOPE, N/U Tree, .Test Tree 12 198 8.3, 0 198 8.3 11 RDMOWorkover Rig i i II I Post'Rig Work. 198 . 8.3 Run Rod Pump and Rods Using 50-Ton Crane .... 198 8.3 Ill II I I ~ubtotal (Days) 8.25 Loss/Trble Time (11%) 0.91 Fotal Project Days 9.16 ilia i 1 i i i Ill i i i i i i i ........ ~ote: Loss, Trouble, Unplanned is based on 11%. Also, the risked troubled costs were included in the AFE costs. SCU 13-34 AFE Est Page 1 of I 4/5/01 UNOCAL API~ 50-133.-20231-00 RKB :16.5' HI TD= 11,551' PBTI~ 11,503' Max Deviation = 32° ~URRENT COMPLETIO~ Swanson River Field Soldotna Creek Unit Well SCU 13-34 Completed 12/71 Casing & Tubing Wt Grad~* ID To~' Btm 18" Surf 70' 10 %" 40.5 K-55 10.050 Surf 3063' T' 23 N-80 6.366 Surf 2537' 7" 26 N-80 62276 . 2537' 4343' 7" 29 N-80 6.184 4343 10,491' Liner 5" ] 18 ] N.,80 14.276 ] 10,283' ] 11,549' Tubing 2-3/8" 4.3 N-801.995 10,208 11,443 Jewelry Item Depth Length ID Description . . 16.5' 0.70' 2.992 Tb~ hanger. Bored 3-1/2" EUE top & btm 17' 2.51 2.992 Crossover, 3-1/2" EUE x Butt 1. Camco 2-7/8"'MM GLM w/1-I/2" R latch & 3-1/2" Butt x-over on each end. (~l_M~ 1. 2042 14.80' 2.441 Camco 2-7/8" MM GLM GLM~ 2. 3679 14.80' 2.441 ~ Camco 2-7/8" MM GLM GLM~ 3. 4877 15.07' 2.441 Camco 2-7/8" MM GLM 13LM~ 4. 5794 14.98' 2.441 Camco 2-7/8" MM GLM t3LM~ 5. 6430 14.93' 2.441 Camco 2-7/8" MM GLM (3LM~ 6. 6913 15.11' 2.441 Camco 2-7/8" MM GLM ~3LM~ 7. 7303 14.92' 2.441 Camco 2-7/8" MM GLM (31_M~ 6. 7631 15.12' 2.441 Camco 2-7/8" MM GLM 2. 10,208' 1.23' 2.441 Crossover, 3-1/2" Butt x 2-7/8" EUE 8rd . 2.a. 1.07' 1.995 Crossover, 2-7/8" EUE 8rd x 2-3/8" EUE 8rd 3. 11,216' 2.84' 1.937 Camco "C' Sldg Sire. Shift up to open 4. 11,250' 5.45' 1.980 Baker "FI-I" Pkr, 'size 43B. 2-3/8" x 5" 18# 5. 11,255' 1.51' 1.875 Otis "S' Nipple. Position #3 6. 11,287' 20.31' 1.995 Baker 2-3/8" Blast Jt. 3.062~' OD 7. 11,307' 1.41' Brown "CC" Safety Joint 8. 11,308 20.32 1.995 Baker 2-3/8" Blast Jt. 3.062" OD 9. 11,329' 2.71' 1.937 Camco "C' Sldg Slve. Shift up to open 10. 11,331' 5.47' 1.980 Baker "FI-I" Pkr, size 43B. 2-3/8" x 5" 18# 11. 11,337' 1.51' 1.875 Otis "S' Nipple. Position ~#2 12. 11,338' 64.46' 1.995 Baker 2-3/8" Blast Jt. 3.062" OD 13. 11,403' 2.82' 1.937 Camco "C" Sldg Slve. Shift up to open 14. 11,406' 5.76' 1.980 Baker "FI-I" Pkr, s/ze 43B. 2-3/8" x 5" 18# 15. 11,411' 0.95' 1.812 Camco "D" Nipple, 2-3/8" 16. 11,443' 2.441 45° Cut on tbs tail Perforations Zone Top Btm I Ft SPF Date[ Comments H1 11,290 11,302 12 4 12/71 H1 11,310 11,328 18 4 12/71 Perftbg 11,314'-11,324' H2 11,341 11,352 11 4 12/71 H3 11,362 11,381 19 4 12/71 H4 11,381 11,400 19 4 12/71 H5 1 t,414 11,445 31 4 12/71 1 3-34 100 80 6o 0 105 q cum Oil Prod Mbb 4 Cum Gas Prod 10 ......... Cum Water Prod Mbbl 102 ~ ~ 10'2 1 10 10000 i Oil Rate (PD) f bbI/d Gas Rate PD~ ( MMcf/d Gas Oil Ratio Mcf/bb 1000 J 100 10 1 0,01 0.001 1971 72 73 /a 75 76 -- 78 79 80 81 82 83 84 85 8( 87 ~8 89 90 ~1 92 93 ~4 95 96 97 98 99 2000 01 ubJect: Swanson Workover Program Date: Wed, 25 Apr 2001 03:02:30 EDT From: STMaunder~aol.com To: bill@fairweather.com CC: tom_maunder@admin.state.ak.us Bill, Doing a little homework. Funny, the phone doesn't ring near as much here. But the new office doesn~ have plumbing problems either. But I digress... I have some questions with regard to the programs. I'll start off with my cryptic diary notes and expand on them. One big question. What rig is proposed? F~3,~-,~~ ~-~ ~ ~'~, ~ SRU 14-15...(191-237)....(301-106)...proposal is to clean out the well, abandon the existing perforations and recomplete.:.request to test BOP to 3000 psi and also not to have a SSV.,.say that the well won't flOw...plan to recomplete as a gas well...might need proposed draWing 1 of 2 -What are the BHPS of the old interval and the new? Unless there is a possibility of a high pressure, zone (there aro a few out thero), 3000 psi sounds appropriate. -You request not to have a SSV since the well will not flow unassisted, but this is a gas well. ts the SSV request an artifact from another program? -Do you plan to do a casing test in the pre rig Work or prior to parring? -How the well will look.after workover is not too difficult to imagine, but a drawing will help as I move it up the line~ -What gas rate is expected? Will 2-3~8" tubing limit the production? -What zone/sand is the new completion in? ~ Zoo,-: SRU 234-15...(160-041)...(301-102)... proposal'is to clean out the well, reper[ and gravel pack the intental and run tubing...BH~ stated at 2785 7~ psi...request 3000 Psi BOP test...need a new drawing...no mention of deleting -This plan is pre~y straight fo~ard. You have the BHP of the intended ~ zone. Are there any others of concern? -The present packer is a fair distance above the PBTD. Fill is mentioned, ~ has it been tagged? -Do you plan to do a casing test in the pre dg work or pdor to repe~ng ~,' and grovel packing? -AlthoUgh you have larger tubing planned for this well, Will it limit ~~' production? ' ~~~ Z.~ SRU 14A-33...(162-017)...(301.103) .... proposal is to cut tubing above top ~ packer and clean out the well, not necessa~ or possible to clean out ,-- deeper...mn tubing shallower, acidize the existing pads and add G zone 4~P peffs..:this is.an oil.well and presently will not flow unassisted..:request ~~ is to not'have a SSV...how do they propose to Sl...will adding the G pe~s make the well floW? -As I indicate, in my comments...is there any intent or need to clean out the deeper inte~als? -You are requesting not to have a SSV on a gas lifted completion. As noted WJ::iI I~UII V¥(JIKUV~I r"-lU~li:il'll above, will adding the 13 perfs make the well capable of flowin§? -If the request for no SSV is approved, is there some shutdown mechanism on the gas lift? -What are the BHPs. The proposed rod pump wells have similar comments. I did talk with Steve. Tyler regarding this proposal some time ago. I would appreciate some detailed information regarding the doWnhole equipment and the surface pumping unit. I have just copied my notes regarding these wells. I don't think they are too cryptic. If you need further clarification, please call SCU 33A-8...(172-017)...(301-103)...proposal is to clean out the well, repairing a 7-518" casing leak by runing a 5" tie back and equipping with a red pump...makes same request to omit SSV...probably more appropriate on this well type...how high will the tie back be?...willit be fully cemented?...BOP and contingencies when using crane?.., is there any liklihood that the Hemlock could flow after reperfing?...need BHPs...will tubing be anchored?...will gas be produced out of a casing valve? SCU 33-33...(176-056)...(301-105)...somewhat similar to 33A-8, plan to clean the well out and complete with rod pump...request, relief on SSV as before...plan to use base oil for workover fluid:..no reperf...why base oil on this one?...Hemlock and G zones already open in this well.:.any plan to test the casing? SCU 13-34...(unsure of permit number)...(301-104)...cleanout and equip with pump...plan to add G zone perfs...similar requests as before...plan to use 6% KCI for fluid Bill, thanks in advance for looking at these cOmments/questions. Please call to discuss. Tom 2 of 2 4/25/01 9:49 AM FW: Swanson Workover Program ' I Name: 900FOLDEDSHIPMENT.jpg1 i 1Encoding: base64 [-~900FOLDEDSHIPMENT.ii3.Clt Type: JPEG Image (image/jpeg) I i Name: 900WEIGHTBOX.jpg [~900WEIGHTBOX. ip.q Type: JPEG Image (image/jpeg) t Encoding: base64 t~Swanson Gas Anchor. doc Type: WINWORD File (application/msword)l Name: Swanson Gas Anchor.doc Encoding: base64 4 of 4 513/01 10:o5 AM Swanson River "Poor Boy" Gas Anchor Gas breaking out of production Production I' Production IProduction Casing 2-7/8" Tubing RXBC Rod Pump Seating Nipple~ 2-7/8" Cup Type w/2.280" ID 2-7/8" Ported Sub I1.660" Dip Tube w/10 rd Box x ½ MS btm -- I 3 jts of 2-7/8" Tail Pipe I I -- ] 2-7/8" Otis "R" type Profile Nipple w/plug, I 2.188' ID 2-7/8" Ported Sub LocSet Packer w/o Element 'PEG image 768x1024 pixels 1 of 2 5/3/01 10:09 AM F~/: Swanson Workover Program Subject: FW: Swanson Workover Program Date: Thu, 3 May 2001 08:47:11 -0800 From: "Bill Penrose" <bill~}fairweather.com> To: "Tom Maunder $E-mail$" <tom_maunder@admin.state.ak. us> Tom, For your information and records: This is the same e-mail I sent you on 511/01 except that I've changed the discussion of BOPE to be used when running rods in the rod pump conversions. Please dispose of that previous message as the BOP discussion was gdeviously in error. Thanks! Bill ---Original Message---- From: Bill Penrose [mailto:bill~.fairweather. com] Sent: Tuesday, May 01, 2001 8:57 AM To: Tom Maunder (E-mail) Subject: RE: Swanson Workover Program Tom, Following each question that you posed is the. answer, preceded with an A: One big question. What rig is proposed? A: H&R Rig #9, being imported from Canada. SRU 14-15... -What are the BHPs of the old interval and the new? Unless there is a possibility.of a high pressure zone (there are a few out there), 3000 psi sounds appropriate. A: BHP of the old interval is 4,900 psi and will only flow water. The BHP of the new interval 'is 3,000 psi and is expected to flow gas. The request for testing the BOPs to only 3,000 psi as well as not installing an SSV is an artifact from one of the other programs. Please disregard it. It is. our intention to test the BOPs to 5,000 psi. -You request not to have a SSV since the well will not flow unassisted, but this is a gas well. Is the SSV request an artifact from another program? A: Yes, as stated above, the SSV request is an artifact. Please disregard it. -Do you plan to do a casing test in the pre r'~ work or prior to perfing? A: We will perform a casing test after plugging the presently perforated interval. -How the well will look after workover is not tOo difficult to imagine, but a drawing will help as I move it up the line. A: I will generate proposal drawings ASAP and get them to you. -What gas rate is expected? Will 2-3/8" tubing limit the production? A: The gas rate is expected to be ~2MMSCFD which will not be limited by the 2-3~8" tubing. 1 of 4 5/3/01 10:05 AM FW: Swanson Workover Program -What ~one/sand is the new completion in? ^: lhe l¥onek 62-$ 8and SRU 234-15... -This plan is pretty straight forward. You have the BHP of the intended zone. Are there any others of concern? A: No, we'll just reperf the existing perforated intervals. -The present packer is a fair distance above the PBTD. Fill is mentioned, has it been tagged? A: No tag run has been made since this interval was perforated. However, the well makes sand so there is probably some amount of fill. -Do you plan to do a casing test in the pre rig work or prior to reperfing and gravel packing? A: No. The perforations are open and the producing pressure will be very iow. -Although you have larger tubing planned for this well, will it limit production? A: No. There will not be enough rate from this well to see the tubing as a limitation. SRU 14A-33'... -As i indicate in my comments...is there any intent or need to clean out the deeper intervals? A: No. We'll just acidize the existing perfs. -You are requesting not to have a SSV on a gas lifted completion. As noted above, will adding the G perfs make the well capable of flowing? A: No. The BHP in the G-Zone is 1600 psi and will not allow the well to flow. -If the request, for no SSV is approved, is there some shutdown mechanism on the gas lift? A: There are 2 manual valves at the surface for shutting in the gas lift. While discussing this.question, the field supervisor, and I decided that we are.uncomfortable with the possibility of a line leak occuring some time before somebody notices and tums off the gas lift gas supply. We therefore withdraw the request to eliminate the SSV. -What are the BHPs. A: Hemlock BHP = 1500 psi. G Zone BHP = 1600 psi I would appreciate some detailed information regarding the downhole equipment and the surface pumping unit, A: Photos and diagrams attached to. this message. I can provide more technical data if you'd like. SCU 33A-8... How high will the tie back be? A: The casing leak is suspected to be at the port collar at 7,332'. The tie-back liner will extend up to cover it, making the tie-back -2500' long. If the leak is found elsewhere, it will effect the length of the liner as the intent is to tie back from the existing TOL to just above the leak. 2 of 4 5/3101 10:05 AM FW: Swanson Workover Program Will it be fully cemented? A: Yes. BOP and contingencies when using crane? A: We plan to use a 2-ram stack consisting of: Top: 2-7~8", 1500 psi WP, 0 - 1-1/2", variable rod rams Btm: 2-112", Model LP-15, 0 - 1-1/2", variable rod rams Each well will use both rams while running the rods, with the bottom set being left on the well as a permanent part of the wellhead equipment (i.e., when it's all done, each well will have an LP-15 BOP left on it and the top ram will be left over for future use in running and pulling rods.). Is there any liklihood that the Hemlock could flow after reperfing? A: No, the BHP is only 1500 psi, not enough to lift the oil column. Need BHPs A: BHP --. 1500 psi. Will tubing be anchored? A: Yes, see the attached gas anchor schematic. Will gas be produced out of a casing valve? A: Yes. SCU 33-33 Why base oil on this one? A: Base oil is being used because the G-Zone is very water-sensitive. Any plan to test the casing? A: No, the perforations are open and the producing pressure will be very Iow. ~ SCU 13,34 BHP = 1500 psi. Please call or write with any additional questions or comments. Regards, Bill 1100SIDE&FRTVIEWBE LTO UT.jpg1 Name: JPEG Image (image/jpeg) t Type: 1100SIDE&FRTVIEWBETOUT.ip.qI Encoding: base64 Name: 1100SIDE&FRTVIEWBELTOUT.jpg · ~,1100SIDE&FRTVIEWBELTOUT,ip.q Type: JPEG Image (image/jpeg) 1 Encoding: base64 ..... Name:, 11.00SiD. E~iEW:ji~g ...... ' Type: JPEG Image (image/jpeg) Encoding: base64 3 of 4 5/3/01 10:05 AM Unocal Corporation P.O. Box 196247 Anchorage, AK 99501 Telephone (907) 263-7677 Dan R. Williamson Drilling Manager UNOCALe Tuesday, April 17, 2001 Ms. Julie Heusser, Commissioner AOGCC 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 Application for Sundry Approval; SCU 13-34 Workover, Swanson River Field, Alaska Dear Commissioner Heusser: Unocal Alaska Resources hereby submits an Application for Sundry Approval for its plan to repair Well SCU 13-34 and convert it to a rod pump completion. SCU 13-34 is a shut-in, Iow rate Hemlock oil producer. The proposed workover will consist of pulling the old completion, re-perforating the Hemlock, adding perforations in the G-zone and re- competing with a rod pump completion. Because this well will not flow unassisted, Unocal requests approval to re-complete this well ./"'~ithout a surface safety valve. For this same reason, we also request approval to test BOPE to a maximum of 3,.,~i. The anticipated commencement of this workover is approximately June 28. Please find enclosed an Application for Sundry Approval (Form 403), a summary workover procedure and a wellbore schematic. If you have any questions or require additional information, please contact Bill Penrose at 258- 3446. Sincerely, //1., Drilling Manager Enclosures cc: Bill Penrose ORIGINAL '~,,~ I~S~tII'TAL AND ACKN[)WLEDGi~Mi;NT 0i' RECI.;iI'I' ()l,' i-h'm'iLl(tAb - (ALASKA) TO: 'DEPT.: PLACE: FD- Folded R - Rolled S - Sepia F - Film X - Xerox B - Blueline THE FOLLOWING IS A LIST OF MATERIAL ENCLOSED HEREIN. PLEASE CHECK AND ADVISE IMMEDIATELY. , ·RECEIVED 8Y REMARKS ON OTHER SLOE, THIS SHEET. CHEVRON U. S2L INC. BOX 7~39 ANCHORAGE, AkASKA 995] 0 A("~3 STATE OF ALASKA ALASK IL AND GAS CONSERVATION C~',~IMISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WELL [] OTHER 7. Permit No. ! 71-21 . . 8. APl Number Anchorage, A~.aLska 99510 ~ 50- 133-20231 .. 9. Unit or Lease Name ~k Unit Li' ~. of the ,~',.5. Cor., Sec. 33, T8~, I10. well Number ----'- "t 11. Field and Po~l DF, et~:.) I 6. Lease Designation and Serial No. i Swanson River Field I A-028990 Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data 2. Name of Operator Chevron U.S.A. Inc. 3. Address P. O. Box 107839, Anchorage, Alaska 4. Location of Well 67.25' N. & 1889.11' W. of the S.E. Cor., Sec. 33, T8N, R9W, S. B&M 5. Elevation in feet (indicate KB, DF, etc.) 143 ' K.B. 12. NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing i-]., 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). lo e A tubing packoff and a PS plug were pulled from the seating nipple at 11,337'. This opened the H3 and H4 sands in the Hemlock Zone to production. A restriction was found in the tubing~ll,350'. This prevented the job being completed as proposed. This work was suspended on 12-3-82. No further work is planned. Signed ' Title Area En~in~_r The space below for Commission use Date Conditions of Approval, if any: By Order of Approved by. COMMISSIONER the Commission Date __ Form 10-403 Rev. 7-1-80 Submit "Intentions" in Tr pl. icate and "Subsequent Reports" in Duplicate February 16, 1983 Ch evro n U. ~. A. Inc. P.O. Box 7-839 Anchorage, Alaska 9'9510 Re~ Subsequent Reports, Sundry Notices and Reports on Wells (Form 10-403 ) For the following lists of "Notice of Intention To~" Sundry }~tices and Report on Wells (form 10-403) this office does not have on record the "Subsequent Report of:- defining the action taken on the approved intention. Please advise this office by Subsequent Report of the disposition of~. the intention. Well' Chevron Date Brief D~scription of_Intention Jeanette Is. 1 SRU 23-27 SRU 24-33' SCU 21-4A S CU.,~ 13-34 SCU 14-34 SCU 21-9 Sincerely, I~nnle C. "~mith Commissioner 1/13 / 82 5/7/82 5/7/82 8/'3/82 8/5/82 81518,2 8/5182 Brier description Clean out scale plug Clean out scale plug Reperforate Isolate leak in H-"3-4# interva2 Return Hi and H2 to production Clean out-fill in tub!~ng LCS/J~T/g lh ' STATE OF ALASKA ALASK IL AND GAS CONSERVATION C MMISSION SUNDRY NOTICES AND REPORTS ON WELLS OTHtE ,~ ~/¢~ 1. DRILLING WELL [] COMPLETED WELL [] 2. Name of Operator 7. Permit No. Chevron U.S.A Inc. 71-21 3. Address 8. APl Number P. 0. Box 7-839, Anch., Ak 99510 50-t33-20231 4. Location of Well 67.25'N & 1889.11'W of the SE cor., Sec., 33, T8N, R9W,S.M. 5. Elevation in feet (indicate KB, DF, etc.) 143'KB 12. I 6 . Lease Designation and Serial No. A-028990 9. Unit or Lease Name Soldotna Creek Unit 10. Well Number SCU 13-34 11. Field and Pool Swanson River Field 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 to perform the attached procedure on Well SCU 13-34. AUG - 6 1982 A!aska 0il & Gas Cons. C0mrnissi0. Anch0ra,~e 14. I herel~y~gertify that the foregoing is true and correct to the best of my knowledge. Signed ' Title Area Engineer The space b[el~ for Commission use,/) Conditions O~'Approval, if any: Approved Copy Returned By Order of Approved by. COMMISSIONER the Commission Date 8/5/82 Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and. "Subsequent Reports" in Duplicate WELL' FIELD ' CHEVRON U.S.A. INC. WESTERN REGION ALASKA AREA WELLWORK PROCE~RE SUMMARY £CU /g- 3at' _~WtIi,CD/V P ~ i);- ? I ', ~ !~_ · TYPE WELL Pf.~DL~ ?~ ": - P." ,JOB NO' TYPE JOB' ////7~:/Zbq-1 L. '7~TT ORIGINAL SUMMARY SUPPLEMENTAL SUMMARY E] NO, ,, · /-/£M/..~.,. K?" , p(,?~,.r'7-?t'.)/:.: ;/-,,,,n -:'~...'7 OBdECTIVE ,o~.)~,~; " /"", .<./q/VD rD p...,:. ,, .....,..,, 15L)/.f}.7'E Z[i-ff~ lA) ,q:Z-'Y" l/J T/:_/e l/P L. ! .WELL DATA' K.B. ,//'¢, L'T ~ CASING' q /:r-' ,If~/'}od'/l.,-, .; LINER ' TUBING ' !/.,1~,. ~m'' ~"7-T~r. , ~'~l~.~ ~R. _,<./-:--::- /q,'T'T~,"/¥~i£,,. . ._ ..~, PERFORATIONS' · NOTES /,~, ?~'" e/.ilF'"; · , ~,, ~ fl'.,," .. :,,. ,,,, , .... .,.- .', .-.-': .' I/l/ ti///._,', /.))t2 .,?,..,,/(~}- · , , ,' . . ; ~.,, ,.~ '. ,, PROGR,,AM ....... .?. ) ?[)L/... "P£" P~/)& P //~57 ' , ~Iff~~' d~~, /4 5 /_)/-.-Fs:.- Dlstributlon: Original to Well File W.D. Sauer (3) Field Office(I) Preparer (I) D.M. Wilson(I) AUG - 6 1982 Ah~ka 0il & 6a$ Cons. ComrnissionApproved by~ ,Anchorage . ./ · Prepared_ by . ,-,Date WELL' PROGRAM (CONTINUED)' CHEVRON U.S.A. INC. WESTERN REGION ALASKA AREA WELLWORK P~DURE :SUMMARY 2 f4r'~£,/::/ ~"' 7T.~ ".7'0P5 ) //~1ii C, '_', ,, CLICK. Lt£".'/? tg, Dt:,Y'£ ~ '~1 lET) t i2 15~/(.?0 ,'q / £ C, ff DETAILS ATTACHED Dls'trlbutlon: Original to Well File W.D. Souer (3) Field Office(I) Pr~:~ {0 D.M. Wilson(I) Oil & Gas Cons. Comtnission Anchorafle Prepared .by,, ' Date ,,, t&'~_ .. .. ~ ( .... ~'LL S CU 1:5- :~4___ I~,$_, ]'.' · L CASING AND TUBING DETAIL I · ][.]3. to TUBING HANGER -" 16.50' · 19.71' ] · TUBRIG HANGER BOILED. ~ EUS TOP a BTM. ' .?O' i " J- . (.~' ~.~, 1.o~,~,u.~, .~, x-o~.) ~.~1. ' ~,~*~.~7 · -3,s78.9~,~-.' · -, ~2 ~TS. ~, S~~ · ~.~ CIJ~0 l~,[ 1/~iDr~L 2~", J# ' , - , 14eS0j · --/,,877.i4'~ . . 38 ~: ~, BUTT~ 1183.1R' - 5,794.43'~ _ ' -.,':~9 ~S. 3~" B~T~ 9C3.22' -- ~ ~ · ~- B~T~ ~1 .O8' -- 7,303.12 '~ · ' 12 JTS. 3~-" BU~P~ ""~ -';, ~ Cl,~O ]~, ~.,D~L 2~ .. 14.92' --~,~o.8~,~ .._'__ , .. ~o ~s ~,, ~~ss 3~.8~, --10,m8.33'~' '" mz~' '-.- ~ ~ X-O~R ~}, B~SS x ~" Eb~ 8rd ' ' '1.23' --11,215.85' 34 ~OZ ' · ' o - .,~~ ' .~ ~ ~,~ "CC" S~ flO~ · . 1.41~ .[-,'' ?, :._., . ,.j. D~.~R BL'~T JT. 2["(2.875")64.46' ~o~' ' ' · ~__ jl.zO~.~,.,~ : C~.~uO C S~ 2~" O~N U~W~. 2.82' ........ ,~ ,AK..[ FH P~l~..ut., 2= x 5" lS~ ~ ~"' d~/4, ~;4]I.DM ~ ~. Ce PI~1 J , . ' · -, .. ¢',' AUG-6 ,':..' .. /~!~ska'Oii & Gas Cons. Cmnmissio. ....... "' /t~chora~9 · ~' '.,'A/-t:VEF, t.o ,~.~:" . -. TRANSt.~TTAL ;~) AC~;0;..T2DG',~ OF RECEIPT-OF ~&~TERIAL~ FXP-140 Under separate cover, we are fo~rarding the follo-~ng material, via COMPANY WELL NAME TYPE of LOG SCALE NO. PRINTS __ , , ~' ~ o?. ~ /z_ . 't3- ~'/ xp / ~- / z ~ ~ , .~ · . .. . .... '. '. .. '~x-/:z...~ /:: ~.~ ' . ",~.., ¢ ,.. · . .. .' .. ' . ' '~ ' '" · . ..c.Z.l tx,'/.. ./... ~',~ 0 '. · · '....'..".' "':'....... .... '.~:,.~.~-n'~'" ' ... ·../__.':'~o" ' · xd~c,~x ~,~; ' "'": .'"..',.' :'."-'.' · '" ' ~ .,~.'.~Z~>~"" '. , ,:~ ~' ' '" ' ,. . .' .. '... ~...'. [ .... : , . ~' . -, " .i. ...'..''. .'.'': '.... .... ' ' '. ~.. :..' · .. .... .. /qr~'' ~_ -'.. .. ,. .... . ... ., . . . . ~ ..' . . . .... . . . . ,.:' . . ...,/......... .. . .,, ~ ~~_~ _ ,,. .: ~ .~ ~/ ': ~ o ,. .. · ,." : ..... :' " ' ' '" ""'""" ' ' ' ' ' :i , '"!: · · . .'. ... . · ' . · .~ , . . ~' - ..' . .. .. ... ' , , · .. . · '." . ': ,. '~' . . · . ' ' ...... " '. ..... ' _ ~ L_ , ~ ,, .... , __ ' If material zs not received %rithin five ~ays, please a~vise i~ediately. ·- .-. .-...,... "- Received aud checked by: ,~~~ ~:~' ' ' ' Re~: o~ o~ ~ Printed in U.So A. / / / iii i ii i i i WELL COMPLETION OR RECOMPLETION RE~(~R~ ~~~~ ! , la. TYPE OF WELL: un, ~ ,,,~ ~ ~ ~ TYPE OF COMPL~ON: NEW ~ WORK ~. N~ME OF OPER~TO~ S I OF ALASKA ~Seeotn/{ st ruction.~ _ OIL .AND GA[ CONSERVATION COMMITTEE, STANDARD OIL CO}fl?ANY OF CALIFORNIA, WOI Conservation Division 3. ,,~,.ss or OPZRA~o~ U. $. ~ICiJLOOiCAL SUB · fi ' P O. Bo:-, 7-839 Anchorage, Alaska 99510 :,:c:aorage, Alaska ~-. LO~ATION OF WELL (Report location cleari~ and i~ accordance tcith salt Crate requirements)* At surface 67.25'North and 1889.11' West of the SE corner of Section 33, TSN, RgW, At top prod. interval reported lielow 1674.99' North and 2480.47' East of Surface Location. At total depth 1725.64' North and 2,519.33' East' of Surface Location. 5 AP1 NTo~'IEH.ICAL CODE 50-133-20231 £ DESiG.N'A%CfON A~%D Sg~ NO. 2399G : ' - 8. UNIT,F~I O~ L~SE N~ME S°ldotna Creek 9. W~L NO. v~U 13-34 10. F~ kN'D POOL, OR WI~CAT Swanson River Field n. SEC., T.. R., ,u.. (nO:'~OM X~OL~ S otU. $crxv~, ec~xonjo, T8N, R9W, SB&M 12. PER1VIIT 71-2I 8-21-1971 12-13-1971 12-24~197! 143' KB a 128.5' si';' io a ' ~IOW ~Y* ROTARY TOOL8 CABLE TOOLS 1,5 ~ 2~'~:%~' 11,503' ;10,781' 0-11~551'. . 1 Top 11,290' ~ 10,574' TVD . Bottom 11,445' I~ 10,725' TVD ~0CK ]. Yes ,.4. mm~zurcrmc ~DOT~-rm LOSSRU~; Dual Induction - Laterolog, Borehole Compensated Sonic - SP, Dip- meter. Cement Bond Lo~. Ga~::ma Ray - Neutron. Casing Collar & Perf Record - -- , 11 , CASING ~ECORD (Report all strings set in w~ll) j Driven '. J None I 3 " ~,~ ~' ' ' 6 ; 15"..{1750 S.acks Class "G" { ' None " ~ ~ ~'~ ,, ~ z ' · ~:700~gc'k~ Class "G" .... 7 i z3.2,:~ .&29v, l. N-80/L~. ~90_ ! 9 7/8" . ~. ~ 9~ ~ ~ ~" . . ..... - [ ~' mm~j~o~[ [ ..,~ , 13 1,- [ 10,2,:7 I , ' L!,250 ~. PE~O~TIONS OPeN TO (interval. size and number) 29, ACID, S[JOT, 4-~~' Jet Holes per foot 11,290~-1L,302~ 4-½" Jet holes per foot 11,310'-11,328' 4 ~" c' '~ Jet Holes per foot 11,341'-11,352' 4-½" Jet Holes per foot 11,362'-11,400' "4-~" Jet.Holes per foot 11,414'-11,445' PRODUC~ON DT~,,'~'Et'i IN'i'IEI~VA_L (MD) / ASiOUN'C AND KIND O.F ,DATE FIRST P~ODUCTt. Oi~I 1 FRODUCT1ON R'!EIHOD (Flowing, gas lift, pumping--size and type of p~np) [WELL STATUS (~oduc~ or -i2-23'-71', t Ylo~ling '" ' _ Il ,"~'~,Producing · ' 12-25-7! 24 · . 74/64 { 19930 InjeCted 32. List O~ AT~CitIIENTS ~l~'14)ikJi~ .... ' ?/"~'~ Directional survey and lo~s listed above " -- 33. X here~y c&~tif~Iia; th~re~-andj~rachet~Snf.,'mation [. complete and correct as determined from all-available records / ...... .. ~ I~" ' ....... ~ .............. , ,. =,=.,, ,'.~7.'U.~ .... .,, , · (See {.slrucfions '! ~t , , ~ 1 ~:.? !:? ~:~. ! I I ~ ~ : :'- Geologic Markers '" ~. , . ,,.. .(', .~ . t. ,.,~. ,.~..~.., :. ~, :::: ,._,,. ,...:.. t~::: ~ {:~. ....3:~ ~ Name' ~',:,' :Meas. 'Depth' : : ~True Vert. Depth ~ ~...~ ,. , ~ - ~ ,:~ ..,...~:_, ~,.: ,~ ~.~: :.:, .:.. :-- ::J~ ~.~,-?.:~- ~:~10 .. : ~.. ~, ~ 8870 , ~ .~ ,83o2. .. ~ · ,"'~; ~;'_ , ,* "~,~ ,.. ~..~:'.:., .... ,...,.'~. '/'.,,.~:": ~'~'~.,. ,-:.,~.~ ~_:,,~;~;'- ;:~ ~:-'i~:,:-":,:':-~HX:".'~-:"~.. 11,288' ." ' . - ~. ~~.. , . ~ .... ~ ~.. ~ ~.~ .... ,, ~,., 1~ ...... ,i,, . ~:~..~.~ ~:~ :'q":~l . ~'~ ..... ~ ~: ' ~ :' '~':-:~;~i':~ ;?~'.~::~... r ~ , 'X', , ' ~'~ t': :~'' i~ ~ ~ U~- :~ ~ ' ' :..~ , ' , ' ~ ' .' '. .' , ' ~ :. ~ '~j ~ L'.'-~:~ -:-: ~ ~; !-;~ i,':~ ~5 I-: ~'. ::~ i ~',.....: : ~ : ~'-:'-~*~' ;~"T~'Tr ~ :..:: ;.." ~ ~. ~ ~: ~'~ ~ ~t-'"'.. " t ~' ~ . i c~ t,:~ :: -: ~ ~ "~ '~ ~ ~ ' ~': i,-i ,..~ ~ - ~:~ ~ ~, . ' ""' '"~ , ~ ~" '" ,-"" I:~' '3c~ j;" .... ~'-: ''~j.~; i, ,~ ..,~ ..... ,_,~ · ~ :.,.. . . t~.,,.. r-~. '~ ~ ,~ · ~ .... ) ~, ~'~(..~ t ...).- f ~. ~ . ... , ,-~ :., ~ ~--'~t:, I~ ~,~:~ i~ i~ ~:i ~ ~ ® e~ ~ ~c~::: .... ~,.~ . ~ ~ .~..: .~, ~ · COMPLETION~ REPORT " NEW WELL ., . STANDARD OiL COMPANY OF CALIFORNIa, ?ESTERN OPERATIONS, INC. OPERATOR " AREA: , SWANSON RIVER FIELD PROPERTY: SOLDOTNA CREEK %MIT · WELL NO.: SCU 13-34 LAND OFFICE: · ANCHORAGE LEASE NO.: A-028990 · API NO.: 50-133-20231 · LOCATION AT SURF,~.~...~:."'"'"~: 67,25' North and 1889,11" West 9f the 'SE corner ~f Section 33, T-8-N, R-9-W, LOCATION AT TOTAL DEPTII: ELEVATION: .. l~arch' f~ , 1972 1726.64' North and 25i9.33' East7'.of surface location., . ~o. .. . 128.5' ground level; KB to G.L.'s i~'1'5' ., i".' "'t. C. V. CHATTERTON / ' - · District superintendent ...... . .... ~ . ~, . . . - -, ..~, ~..,: · .. '.. . DATE: .. ~.'~'~ 9"~ ................. '~':'- .... '~'"" DRILLED BY: R~ B.' MONTGOMERY DRILLING ' 'DATE COMMENCED DRZLLING: 8-21-71 DATE COMPLETED DRILLING: 12-24-71 · DATE OF INITIAL PRODUCTION:~12-23-7! RIG #35 -. · - ' SUM MARY . -..._TOTAL DEPTH: 11,551' Effe, ctive DeR_th__: 11,503' \ ~ 18" CASlN=: Line pipe at 70' (driver~) ~ , 10 3/4", K-55~ Buttress at 3063' '. cemented at 3063' and !060~ 7" N-80 & P-110, 29, 26 aD~d , 23# at 10490' cemented at '"'· ~ 10490' and 1678' 5",'-'N~8'0, 18.~/ liner from 11549'- 10283' cemented at 11549'. PLUGS: in .5" liner 11551'-11503' cemented fish in 2nd sidetrack ~ 10805 '-11547 ' S!DETK~CKED HOLE: '.Ist sidetrack - 9 ~'/8" hole from 10550 '-11014' 2nd sidetrack 10805'-11547' . ~ Fish from 10934'-11547' in, ~ 1st sidetrack (cemen22ed) ~ E~~':'-'' ''' ''~ '~ ~i''~' r'~'~'''~:'~ ,,~ ',; DIVISION OF OiL JPERFORATIONS: 7. SUMMARY (CONT'D) 4 -1/2" Jet ,Holes per foot 11,290'-!1,302' 4- 1/2" Jet. Holes per foot 11,310'-.11,328' 4 - 1/2" Jet Holes per foot 11,34.1'-11,352' 4- 1/2" Jet Holes per foot 11,362'--11,400' 4- 1/2" Jet Holes per foot 11,414'-11,445' Dual Induction - Laterolog - 3065'-10204'; 10490'-11551' Borehole Compensated Sonic - 10,490;-11,551' Gamma Ray - Neutron Log - 10,250'-11,503' Cement°Bond Log ~ 9274'-10,379'; 1t,250'-11,482' " -t-Arm High Resolution Dipmeter - 10,49b'~11,551' Casing Co±z=r Log and Perforating= Record - 11,073'-11,462' Radioactive Survey - 2500'-5400' ' Temperature Log - 2500',5400' .. <INITIAL PRODUCTION: · -' METHOD - Flowing OIL - WATER - DRILL STEM TESTS: ./ · None. GAS - GO R - 1695 barrels per day, 35.1~ API Gravity 30 day ay. sands 1-4 . 3 bbls. per day . .. ~· 7700 .1430 psi on spool COMPLETION REPORT WELL # SCU 13-3~ [ Sec. 3.3 T. 8 N., R.~.,,J W.~_j SB&M Page 3 August 21~ 1971 Drove 18" conductor to 70' while rigging up. Drilled 15" hole to 100'. 76 PCF _~ugust 22 - 26, 1971 Drilled 15" hole to 3110'. Pipe stuck at 348'. Back-off fish. Picked-up bumper sub. Screwed back into fish and jarred fish loose. Ran 10 3/4" 40.5,q K-55 casing, stopped at 3063'. DV collar at 1060'. , 76 PCF Cas in£:~ Detail 76 Joints, 10 3/4", K-55, 40.5#/Ft. Buttress including float shoe, float collar and stage collar - on hook 3079.94' - Above K/~- 16.94' Shoe at 3063.00' .' Cementing Detail Cemented 10 3/4" in ~o stages as follows: · · Pumped 200 cubic feet of water ahead. Followed by 1000 sacks of-Class cement. Displaced with 1690**aubic feet of water. Good circulation. Cement in place 10:30 AM 8-26-71. Opened stage ports. Circulated out cement contaminated mud. Pumped in 650 sacks of Class "G" cement. Displaced with 580 cubic feet of mud. Had approximately 400 sacks return at the surface. Cement in place 4:30 PM 8-26-71.. / .. ., .Top_ Located top of cement in 18" x 10 3/4" annulus at 30'. Washed down to 60'. -Cemented with 100 sacks of Class "G" cement. Cement in place at 10:00 PM 8-26-71. Cut ~f~f"~ 3/4" casing, wJlded on casing head. Tested ~ to 2500 'psi - OK. A_~ust 27-28, 1971. Nippled up 10"-5000# BOPE. Tested to 2500 psi - OK. Drilled out stage collar at 1060'. Tested ports to 2500 psi - OK. Drilled 9 7/8" hole to 3725'. · , , COMP L'i'X I ON REPORT "( t.'ill, L i; SCU 13-34 SEC. 33 T.8 N., R. 9 W., SB&M Page 4 A..U,gUSt 29-30, 1971 'Drilled 9 7/8" hole to 4000'. Ran Dynadrill ~']1 4000'-4077'. Directionally drilled 9 7/8" hole 4077 :-4610' : 73 PCF August 31-Sc;pt. 30~ 19.71 Directionally drilled 9 7/8h hole to 10,768~ Dynadrill ~,~ from 5481' to 5559' Dynadrill I~3 from. 5800' to 5959' Dynadrill f/4 from 6041' to 6255' Dynadrill l/5 from 7515' to 7587' Dynadrill I/6 from 8784' to 8832' Dynadrill ti7 from '10,261' to 10,299" . · . . .. · October 1-3, 1971 '73-97 PCF · 7 " . Ran Dual Inductipn Laterolog from Diremtionally drilled ? /8 hole t° 10,817' 3065' to 10,204'. Directioti.a!ly.drilled 9 7/8" hole to 11,014'. Whi~le drilling ............... ' . ~DJ_~L ~;!~ '-'- '-'--~ ;' . at ]].~Ol~' ga~d 50 ~arr~l.~ ~F m,,~ ~n pits ' ~'' ...... ~ ~- had 6fl~ oras'sur~ bnilH- up on casing. Circulated with 30 pump strokes per minute, holding 200~~ on choke and 600f! on drill pipe· Lost circulation. Mixed 40 bbls. 98f~ PCF with LCM and spotted on bottom. Tripped out of hole and ran in to shoe of casing. -Unable to fill hole while tripping pipe. 87-98 PCF . . October 4-6, 1971 ~ , . Pumped 180 bbl. 80~,~ mud with LCM thru bit @ 3040'·..in ..... stages. Mixed and filled annulus ~ith 66f~ gel water and LCM, in 50 barrel stages. Hole would not stay full. Pulled to 2000' to establish circulation. 'Had returns 5 minutes' then lost circulation. Started to trip out. Pulled to 1488' and well started flowing. Ran-to 2000' where it was necessary to shut~ well in. Had 25°0 psi on D,P. and 50 psi on annulus° Circulated 85~ mud thru choke to keep pit level constant. Raised mud weight to~ 95 PCF, well dead. Ran t.o 3041'. Well started flowing, closed Hydril to mix diesel-bentonite plug. Used 180 cu. ft. diesel and 30 sx. gel. Displaced to 3063', (bottom of 10 3/4-'caSing shoe). =Pumped mud in 10 3/4" x drill pipe annulus · while displacing diesel and gel out bit. Diesel-bentonite squeeze in place at 3:30 PM. Final pressure 800 psig. After '4 hours bled Off pressure and circulated 95f~ mud. Pulled and laid do~m drilling assembly. Ran to 3245'. Took 6000f~ wei_.ght then'broke thru. Tripped to 5430'. Mit bridge. Hole standing full, but no circulation while cleaning out bridge. Cleaned ou.t...~t0~...5._.4.~4.~.,, .......... - · .CO}~I.ETION P~EPORT 'WELL ~,~ 'SEC-. 33 T. 8 N.,R. 9 W. ,'SB~{ page 5 .. -. October 7-8, 1971 Mixed 300 bbl~ 95# mud with LCM. Starter pumping do~m D.P. Had circulation irmmediately. After 5 minutes mud pits s'tarted gaining. Closed well in with 50 psi on annulus 0 .psi on D.P. Circulated thru choke to keep pits level. Mud weight cut from 95~t going in~ to 85fI .coming out. Pumping pressure 50f~, b:ack- pressure on choke 50~/ to' 200~.closed well in to conaition mud. O'psi on D.Pi 275# on annulus. Water sample check, 2.0 g/g, Ph 8.0, viscosity '29. Pumoed in-. 95~! mud and LC}I, returns thru choke~ 58~-80~~ flowline, 9]_~/~-93~ @ degas~er discharge for 1 hour and 10 minutes. Water for 20 minutes. Shu~ wall in wi_.t.~_2_2__p.!~ on annulus and 0 on D.P. Ran Temperat. ure and Radioactive"'s-urvey. Estimate loss circulation zone 3063'-4400'. ? :' 632 95 PCF pc_ tober 9-13, 197! .." . .. ~. Well shut in with 250f~-400~ on annulus and 0 on D.P. Mixing 120~/ mud, installing Shaffer combination rotating head, blow-out preventer, and stripper. 95 PCF .. October 14-t7, 1971 '- . . Tripp~.d ~n hole from 5440'. Reamed and drii~ed' out ~_r_.i.~ge~. at following, de~tb:s' ..... ~.~./~" ~-5349 ~ and 5700: to 6950~. Circulated., on choke. Mud weiga~ ..... with-70-86 P'CF"'r~'~'i ..... ShUt'in easing pres~6re I0021-50--'~%'ig,'.drili'-'pipe ................................. · 70-90 P CF . . - .: . October 17, 1971 '-'' ' R~ in hole, hit hard bridge ~ 5671' . (Hole staYed full during trip.') Couldn't establish circulation. Pulled to 3027.', ~ . .. 90 PCF . - --. October 18-19~ 1971 -- .. ~xed 80 sack diesel-bentonite pill. Displaced to 3070', 950:psi final shut pressure, held 250 psi on casing for 4 hours. Located plug at 3126~. Cleaned out to 3158'. R~ to 3300' circulated. Ran to 3500', took weight. Circulated out gas-cut mud 78-83 PCF. Casing pressure 175f/, D.P. pressure 100~/. Tripped 4468~ cleaned out ~~e. Mud retu~s gas and water cut to 6~-72 PCF. Tripped to 6778' cleaned out bridge. Mud 90 PCF going in and 80-84 PCF coming out. Cleaned out bridge ~:697~',. circulating 90f/ mud in with 84~/-88~/ coming out. Controlling well with pump pressure, 2" choke" op~n~ ......... ........ -- '- 90 PCF ... - , .' ': . - . . . COMPLETION REPORT (~ '::i' ~WELL # SCU 13-34 "' SEC. 33 T. 8 N.,R. 9 W., SB&M Pa§e 6 October 20-26, 1971 Drilled through bridges at 7134', 7325' and 7417'-7448'. Slight mud loss at .times. Well wouid flow with pump off. Gas cut mud at 7417' (68#-72#) at flowline. Raised mud weight in stages to 93 PCF. Controlling well with pump pressure. Choke open. Clean out coal and shale bridges and circulated and conditioned mud in stages from 732~. Gradually raised wei-ght to 96'P~F. Stuck pipe at 9174' while rotating through bridge, tIad full cir. culatio~. ~4ixed 50 bbl. invernmul. Spotted 10 bbls. around bit and collars. Worked pipe and moved oil 3 bbls. at 1 1/2 hour intervals. Ran Go International. ' Free Point Indicator. Rm~ string shot. Shot drill collar tool joint at-9142'. Pulled out of h01e leaving 32.33' of fish in hole. Made up fishing tools and mixed 150 bbls. mud with L~M added. Screwed into fish and jarred loOs. e. Pulled fish out of hole. Had full circulation with. 96 PCF mud. 96-PCF · , October 27-November 2, 1971 · .. Tripped in :~ith drilling .jars in string. Cleaned oUt bridges 9051'-I1,014'. ~'- .. Full circulation. Had to jar loose several times from 9174'-9214'~. Circulated and conditioned mud at 11,014'. Tripped and ran open ended drill pipe to 11,002'. . .- ,. Conditioned hole for .7:' casing. ' 97 PCF ~ ' - '",' ' "" ':,i" . ' '.'~ · ' ' ' ' ' ' , . -Ran 7" casing. Stopped at 10,490'. 'Cemented at 10,490". Stage collars at 1678' -~ ...... and 6641', Ran two._~cememt baskets~ below__~top._s~aga..~c~llar,._at_167.8'- ........ Installed tubing head, tested secondary packoff to 5000 psi - ok. Nippled up 10"-5000# BOPE .. ............ and_tested ok to 3000 3~si.. ,... 'Above K.B. K.B. - G.L. Length 2.34' 16'.50' .. ,. 7" Casing Detail · -. . Size Weight Grade Thread K.B. Depth' Top 41 joints D.V. Collar Nex~ 20-joints Next 43 joints Cross-over Next 54 joints D.V:-Collar Next 3 joints Cross-over :, Bottom 91 joints 1664.10' 3.00' 854 · 16 ' 1784.23' 21.13' 2297.61 ' 3.00' 129.37 ' 9 .'45 ' 3708.04 ' 7I, 7" 7" 7" 7" 23# N-80 Buttress 16 80'~ 60 ' Buttress 1683.60 ' 23# N-80 Buttress 2537.76 ' 26# . N-80 Buttzess 4321.99~ N-80 Butt x 8rd 43~3,.12' 29# N-80 8rd 6648.73' 8rd 664-~. 73' 29# N-80 8rd 6773.10' N-80. 8rd × Butt 678.2.55' 29# P-ilO Buttress 10490.59 ' On Hook - 253 .253 j.oints" 10,Z~92.93' Less - 2.34.' above 10,490.59' K.B. · COniLl:, ION REPORT . ' ' WELL f/ SCU ].3--34 SEC. 33 T', R. 9 W., SB&M '. ~age 7 · 7" Cementing Detail Cemented 7" casing in 3 stages as 'follows: 1st Stage . . Cemented through shoe with 500 sacks of Class "G" cement w/ 3/4% CFR 2. Lost circulation while mixing and pumping cement in hole. Displaced cement with 2270 cu. ft. of mud. Bumped plug on baffle with 2000 psi at 10,364'. Cement in place at 5:30 AM 11-3-71. 2nd Stage Dropped bomb to ooen D.V. Collar at 6641'. Pressured up and couldn't get D.V. Collar to open. 3rd Staff_ -Dropped 'bomb to open D.V. Collar at 1678'. Pressured up and b'roke circulation with 700 psi. Cemented with 200 sacks of Class "G" cement with 3/4% CFR 2. Displaced cement and closed D.V. Collar with 2000 psi. Cement in place 6:00 PM .11-3-71. . . .. ... November 7- 9 1971 .Ran 6" bit. Tagged cement at 1648'. Cleaned out cement 1648' to 1677' and D.V. Collar at 1678'. Tested Hydrii '"and D.V. Collar OK with 2500 psi. Ran special shifting tool. Tagged D.V. Collar at 6641'. Set 60,000~/ weight on sleeve to shift D.V. Collar ports. Por.ts opened and closed. Tested OK to ..2500 psi. Drilled out float collar at 10,364' and cleaned out to 10,400~. · .Conditioned mud. Ran Schlumberger Cement Bond Log from 10,379' to 9274' Under 2000 psi surface pressure. :November 10 - 22, 1971 97 PCF Drilled out 7" shoe at 10,490'. Started to clean out original 9 7/8" hole to 1]~014'. Sidetracked original 9 7/8" hole at 10,550+--. Drilled 6" hole 10,550'- 11~105'. Drilled with 6" diamond bit 11~05'-1~169'. Drilled 6" hole 11~169'- 11~547', where drill pipe stuck. 9 8 PCF WELL f! SCU"13-34 · Page 8 November 23 - 27, 19~1 Mixed 30 bbls. of 98f~ oil base mud. Spotted 10 bbls. around drill~ collars. Worked pipe. No results. Ran Free-Point Indicator. Wouldn't go below 10,870'. Ran back off shot, stopped at 10,600'. Built pack-off assembly. Circulated String Shot f~l .to 11,462'. Fired shot. No results. Ran String Shot f~2 to 11,403'. Fired shot. No results. CircUlated Free Point Indicator down and found drilling string free to 11,475'. Fired String Shots f~3 to f~ll from 11,462' to 11,000' with 12-14 turns of left hand torque with no results. Ran Free Point Indicator. Found Free Point at 10,900'. Ran String Shot f~12. Backed off at 10,878'. 98 PCF November 28 - December 4, 1971 Made up fishing tools. Ran .in hole and screwed into fish at 10,878'. Jarred on fish with no results. Ran combination Free-Point Indicator and String Shot. Found pipe partially free at 10,937'. Fired String Shot f/13. Pipe backed off at 10,937'. Pulled and laid down 59' of fish. Ran in and screwed into top of fish at 10,937'. Spotted 10 bbls. oil base mud around fish. Jarred on fish. No results. Stuck fishing tools. Ran String Shot and back off at 10,937'. Pulled to 10,867' and conditioned mud to cement fish in hole. Cemented 613' fish. Top of fish at 10,934' and bottom at 11,547'.. Fish left in hole consisted of 6" bit, reamer, 4 3/4" x 10' lead D.C. stabilizer, x-over sub, 4 3/4" x 26'~ monel D.C., stabilizer, 19 - 4 3/4" x 559' D.C., and lower half J-tool releasing sub 3'. 98 PCF Fish Cementing Retail ls t St age' Screwed into fish with "J" releasing sub. Circulated 25 cu. ft. of water-ahead of 85 sacks of Class "G" cement w/ 3/4% CFR-2. Displaced with 422 cu. ft. of mud. Full circulation throughout job. Cement in place at 5:45 A.M. Released J-tool and pulled to 10,470'. Back souttled cement cut mud. Down squeezed using hesitation method. Pumped 5 cu. ft. every 10 minutes. Final pressure 1750 psi. Held 1 hr. Located top of cement at 10,898' and cleaned out to 10,930'. 2nd ' S t a,g~e_ Ran in hole with open ended drill pipe to 10,925'. Equalized 65 sacks of Class "G" cement w/ 3/4% CFR'2 and 20% sand. Cement in place at 7:40 AM. Pulled to 10,455' and back scuttled cement cut mud. Down squeezed using hesitation method, 10 cu. fto every 10 minutes. Final pressure 2000 psi. Held 1 hr. Located top of plug at 10,805' December 5 - 13~ 1971 ! Ran Dynadrill ~/8 from 10,805' to 10,834'. Sidetracked fish on low side. Direction- a!7tY d=i~t, led 6':..h~!e?~f-rom 10,834'-11,551'. Conditioned mud for logs. COb[PLETION REPORT ~.PELL ~t SCU 13-34 · SB &M SEC 33 T. 8 ~N. Page 9 December 14, 1971 Ran Schlumberger Dual Induction Laterolog from' 10,490' to 11,551'; Borehole -~ Compensated Sonic Log from 10,490' to 11,551'; 4-Arm High Resolution Continuous Dipmeter from 11,551'-10,490'. Conditioned mud for 5" liner. December 15- 16, 1971 Ran and cemented 5" liner from 10,283' - 11,549'. Liner Detail Length Size Top of liner Setting collar ~Casing Nipple T.I.W. Liner hanger Crossover Top 20 joints Marker joint l~ext 9 joints Bottom joint including float collar and shoe Total of 31 joints, float ~collar and shoe, and liner hange~ ' 3.73' 5" 8.12 ' 5" 4.15 ' 5" · 74 ' 5" ' 826.1.6 ' -' 5" · 10.0.7' 5" '370.33' 5" -43.17' Weight Grade Thread~ 18f/ N-80 18f/ N-80 18~/ N-80 KB Depth 10,283' 10,286.73' 10,294.85' 10,299.00' Butt.x8rd 10,299.74' Butt. 11,125.90' Butt. 11,135.97 ' Butt. 11,506.30 ' 5" .18f/. N-80 Butt. 1266' " II,549.47' 11,549.47' (Btm liner) Cementing Detail Pumped 20 cu. ft. of water ahead.of 175 sacks of Class "G" cement with 3/4% CFR-2. Displaced with 582 cu. ft. of .mud, ~.~BumDed plug with 2500 psi at 8:30 PM. Good circulation throughout. Pulled tO..10,280' closed pipe rams and down squeezed with 15 cu. ft. of mud to a final p~essure of 2000 psi. Back scuttled. No cement or -cement cut mud. December 17 - 2~.,~ ..19.71 Picked up 2 3/8" tubing. Ran'in hole and tagged ce~nent at 11,503'. Conditioned mud for Cement Bond Log. Ran Schlumberger Cement Bond Log from 11250'-11482' and Gamma Ray-Neutron Log from 11,503' to 10,.250~'. Ran Schlumberger 3 3/8" O.D. -carrier guns and perforated 4 - 1/2" hyperjet holes per foot at the following intervals, DIL depth; 11,290' to 11,~302"; 11,310' to 11,328'; 11,341' to 11,352"; 11,362' to ~!'!,.4Q~0'.;.,..~1,414' to 11,445'. Ran 5" Casing scraper to 11,503' and mudi~fo~ tubing. Ran .and hydro tested to 5000 psig; 37 .joints of 2 3/8" .323~13o~ts~.~ !~ ~--. i' offS' ~ 3 1/2" .tubing; 13 nipples, sleeves, mandrels; blast jdin-ts.; d 3 - 2 3/8" x 5U-,iB'aker FH packers. Packers at following depths: 11,405', Page 10 Ran Gamma-Ray log to tie in Packer~ setting depth.. Spaced out. ~Landed tubing hanger with Casasco back pressure valve. Installed x-mas tree. Tested OK ~to 5000 psig. Removed Cosasco back pressure valve. Displaced well with lease crude oil. Set packers. Released.rig at 11:00 AM 12-23-71. ~0~fPI. ET!ON REPORT · ' ~' 'WELL f/ SCU 13-34 · ' SEC. 33, T. 8 ,N.~R.:-9 ~,_~ ,qB&M Page 11 Tub ing KB to tubing hanger Hanger-(6"x3 1/2" EUE Top & Btm.) 2 Pup joints X-over 65 joints 2 7/8" Camco MM mandrel w/ x-over to 3 1/2" Buttress 52 joints 2 7/8" Camco MM mandrel w/ x-over to 3 1/2" Buttress 38 joints 2 7/8" Camco MM mandrel w/ x-over to 3 1/2" Buttress 29 joints 2 7/8" Camco MM mandrel w/ x-over to 3 1/2" Buttress 20 joints 2 7/8" Camco F~{ mandrel w/ x-over to 3 1/2" Buttress 15 joints 2 7 / 8" Camco ~IM mandrel w/ x-over to 3 1/2" Buttress 12 jolnLs 2 7/8" Camco M~{ mandrel w/ x-over to 3 1/2" Buttress 10 joints 2 7/8" Camco MM mandrel w/ x-over to 3 1/2" Buttress 82 joints x-over 3 1/2" x 2 7/8" x-over 2 7/8" x 2 3/8" 34 joints .2 3/8" Camco "C" sleeve 1 joint Baker "FI{" packer, 2 3/8"x5" 18# Otis "S" nipple, position #3 1 joint 2 3/8" Blast joint Brown "CC" safety joint 2 3/8" Blast joint 2 3/8 Camco "C" · sleeve Baker "FH" packer, 2 3/8"x5 18# Otis ~"S" nipole, position ~2 2 3/8" Blast joints 2 3/8 Camco "C" sleeve Baker "FH" packer, 2 3/8"x5" 18# Camco "D''~ nipple ~---! .~join t- ~- ~_.To't-:al::, ,.~.. : 360 joints tubing, 5 Blast joints, 14 sleeves~ mandrels, nipples, 19 x- it'!'~ ~i overs, 3 packers Size 3 1/2" 3 1/2" 3 1/2" 3 1/2" 3 1/2" 3 1/2" 3 1/2" 3 1/2" 3 1/2" 3' 1/2" 3 1/2" 3/8" 3/8" 3/8" 2 3/8" 2 3/8" 2 3/8" 2 3/8" 2 3/8" 2 3/8" 2 3/8" 2 3/8" 2 3/8" 2 3/8" 2 3/8" Weight Grade Thread 9.3# N-80 8RD 9.3# 8RDxButt. 9.3# N-80 Buttress 9.3# N-80 Buttress 9.3# N-80 Buttress 9.3# N-80 Buttress 9.3# N-80 Buttress 9.3# N-80 Buttress 9.3// N-80 Buttress 9.3# N-80 Buttress 9.3# N-80 Buttress N-80 Butt.xSRD N-80 8RDx8RD 4.6# N-80 8RD 8RD 4.6# N-80 8RD 8RD 8RD~ 4.6# N-80 8RD 4.6# 8RD 8RD 8RD 8RD 8RD 8RD 8RD 8RD N- 80 8RD ~ngth KB Depth _ 16.50' ' 16.50' .70' '17.20' 1.57' 18.77' .94' 19.71' 2022.68' 2042.39' 14.80' 2057.19' 1621.73' 3678.92" 14.80' 3693.72' 1183.42' 4877.14~ 15.07' ....... 4892.21' 902.22' ....... 5794.43' 1B.98' '~809.41~ 621.08' 6430.49' 14.93i .... 6445.42' 467.45' 6912.87' 15.11' 6927.98' 375.i4'~ /303.1'2; 14.92' '7318.04' 312.83' 7630.87' 15.12' 7645.99' 2562.34' 10,208.33' 1.23' 10,209.56' 1.07' 10,210.63' 1005.22' 11,215.85' 2.84' 11,218.69' 30.95' 11,249.64' 5.45' 11,255.09' 1.51' 11,256.60' 29.93' 11,286.53' 20.31' 11,306.84' 1.41' 11,308.25' 20.32' 11,328.57' 2.71' 11,331.28' 5.47' 11,336.75' 1.51' 11,338.26' 64.46' 11,402.72' 2.82' 11,405.54' 5.76' 11,411.30' .95' 11,412.25' 30%7~' 11,443.0' 11,443.00' and PlAN JA N'I 7 197~ SUB-$U'.~EACE SURVEY STANDARD OIL- CALIF. S.C.U. 13-34 .~o]~ ~CL&--_4074- S.O,C. 0 02 DAT'~. i-6-72 HAROLD BROWN COMPANY 8115 LLOYD DRIVE AI~ICHOR. AGE, ALASKA 99t50~' HAROLD BR£~WN COMPANY DlflfCTIOtlfA L DRlll iiVG SUflVEY B,~TA SHEET COMPANYL STANDAPD OIL CO. OF CALIF. ~'?.O,~._L, DATE_ JANUARY 6, 1972 SHEET NO. I job NO. A4074 S.O.C. 002 WELL 13-34 ~q ~ ~ FIELD SWANSON P. IVEP BOROUGH TRUE TOOL MEASURED DRIFT VERTICAL DEVIATION 'j DRIFT RUNS DEPTH ANGLE DEPTH COURSE DIRECTION ~ .' I 125 3°. 124 99 1~64 SOUTH 325 ½° 3'24 98 1 75 S10E 730 ¼° 729 98 1 77 S65E 1250 ¼o. 1249 98 2 27 555W 1671 ½° 1670 96 3 68 S27E 2073 ±' 2072 96 1 75 S20E 4 2521 ~0 2520 94 .3 91 525E 2861 ~o 2860 91 4 45 SOUTH 4 3105 ~0 3104 89 3 19 SOUTH 4 3.535 i° 3534 89 1 87 S76W 4000 ~'° 3999 '89 2 03 .N85W 4054 1¼° 4053 88 1 18 N17E' 4154 3 * 4153 74 5 23 N46E 4284 7 * 4282 77 15 84 N61E 4409 9½+ 4406 06 20 63 N57E ~'-- 4567 14~-* 4559 20 38 89 N53E 4692 18½' 4'677 74 39 66 N54E 4819 22½* 4795 07 48 60 N57E 4944. 27¼° 4906 20 57 23 N61E 5102 284~* 5045 38 74 78 N62E . 5324 28~* 5240 94 105 08 N65E 5481 27~'~ 5379 88 73 10 N66E 5582 ' ~* 244, 5471 97 41 48 N61E · · 5674 23~-* 5556 i8 37 05 N62E 5738 25'* 5614 18 27'O5 N63E 5800 '27~° 5669 05 28~ 87 N64E 5895 28 * 5752 93 ill 60 N60E 5980 24½* '5830 28 35 25 N63E 6041 26 ' 588.5 11 26 74 N63E · 6102 26~-° 59'39 82~~26~.98 N58E KENAI STATE AL/k~KA RECTANGULAR COORDINATES NORTH SOUTH EAST WEST ,, 1 64 3 36 30 4 11 1 90 5 41 04 8 69 li 71 10 33 2 31 13 87 3 96 i 18 32 3. 96 , 21 51 3! 96 i 21 96 2 15 j 21 78l 13 20 65 47 17 02 4 23 9 34 18 08 I 90 35 38 25' 30 66 44 48 61 98 53 75 08 139 29 83[ 189 34 102, 137 941 255 37 :LS 6 2~j i9 453 67 2 158 486 38 26tj 86 510j 48 2741 52 "' 535 43 2961 82 575 05 312 82 606 46 324' 96 630 29 3391 26 653 17 _J___ ...... L DOG-LEG SEVERITY .60° .13' ,10' .12° .06° .06' .11' mm ~m 4e -- 2.35° 2,02' 3.21' 2.05' 3.05' 3.42° 3,27* 4.03° 70* 64° 44* 09* 68' 50° 40* 46' 64* · · 4. 1. 2. 4. 1, 4, 2. 3, COMPANY STANDARD .OIL CO. HAROLD BRC, WN COMPANY DIRECT~O/ifA [ gB/tllllf6 SURVEY DATA SHEET OF CALIF. W.O.I-. DATE JANUARY WELL 13-34 S.C.U. -FIELD SWANSON RiVEP BOROUGH SHEET NO. 6, 1.972 JOe NO. A4074 S.O.C. 002 ' ' TRUE TOOL : 'MEASURED DRIFT VERTICAL DEVIATION DRIFT RUNS DEPTH ANGLE DEPTH· COURSE DIRECTION , ,. . ~ · · 6133 26~~°. . -5967 62 13 71 N57E 6164 25-½° 5'99.5 60 13 35 N55E 6195 2.4-~'-° 6023 .86 12 73 N53E 4 · 6225. 2.3s-°:; 6051' 32 12 08 N5.2E' 6267 23½° .6089 84 16 .75 . N49E 6394 26¼° 62.03'.74 56 17 N47E 6455 28 °' 6257, 60 28 6-4 N47E 6644 · 28 .' · 6424 48 . 88 73 N.49E 6836 28½° 6593 21. 91 61 NSOE . · 702.4 .28½° 6758' 43 89 71 NS2E 7086. 2.8½-0 " 68'12 9.2 29 58' N52E . 73..08' 28¼' ' 700.8 4:8 105 08 N55E. 7515 ' 27-~-° 7191 67 '. 96 38 N56E 7623 26½° 7288 32 '48 ~ !9 NS1E .78.18 31 ' 7455 47 100 43 N53E ~_~ 7972 32 ' 758'6 07 .8.1 61 N54E 8050 32 ' 765.2 22 41 33 N54E 820'0 31 ' .7780 80 77 26 .N56E 8387 30¼° 7942 .34 94 .20 N57E 8'52.2 30¼' 8058 96 68 01 N58E 8713 30½° 8223. 53 96 94 N61E 8887- 27½' 8377 87 80 34 N56E 8919 27½° 8406 25 14 78 N56E 9'067 28½° 8536 32 70 62 N55E 9'264 28{~° . 8709 45 94 O0 .N55E · 9467 '30 ' 8885 25 101 50 N55E 976'0 29-~-° 9140 2'7 144. 28 N60E 9905 27~' 9268 59 6'7 51 N60E 10069 26-,~° 9415 '36 73 1-8 N63E I 10150 .27~'O ' 94'87. 37 r. 37 09 i N64E RECTANGULAR COORDINATES DOG-LEG ,, , NORTH 'SOUTH EAST WEST SEVERITY 346 73 664 67 1.42° - 354.39i . 675 61 3,71° 362 05 .685 78 4.87 36,9 49 695 30 2.13' ' 380 48 707 94 2.93' 418 79 749 02 2.27' 438 32 769 97 2,87' 496 53 836 94 .50' 5.55 42 907 12 .36' 610-65 977 81 ';51' · 628 86 1001 12 .... 689' 13 1087 20 ,65' 743 02 llb7 10 ,33' '773 35 1204 55 2.41 ° 833 79 1284 76 2. 881 76' 1350 78 .73' 906 05 1384 22 .... 949'25 1448 27! ' .97° 1000 56 1527 27 .'49' ' 1036 60 1584 95, .37' 108'3 60 1669 74 .81' 1128 53i 1736 35 2.21° 1136 79 1748 60~ 1177 30' 1806 45 .74' 1231 22 1883 45 .... 1289 44 1966' 59 .74' 1361 58 2091 54 .86' 1'395 34 2150 O0 1.21' 1428 56 . 221520 1.13' 144% 8'21 2248 54~ . 1.09° [ · · __ COMPANY STANDARD OIL CO. HAROLD BROWN COMPANY DIRECTiOAfA ). SURVEY DATA SHEET OF CALIF. W.O.I. DATE JANUARY 6, SHEET NO. 1972 JOe NO. A4074 S.0.C. 002 · ~' ' KENAI ALASKA WELL 13-34 S,C U, FIELD oWANSOh RIVER BOROUGH STATE I~IFT RECTANGULAR COORDINATES DOG-LEG · !CTiON NORTH SOUTH . EAST WEST SEVERITY ,, 66E 1465 14 2294 18 .94' 56E . 1490 39 23311 62 5,03' 56E 1498i 18 2343 17 2.63' 38E 1573 60 2402 09 2.28' 40E 1595 95 2420 85 2.43' 37E 1622 05 2440 52 .50' 37E 1643 09 2456 37 .70' 37E 1726 64 2.519 33 .... ,, OSURE --305~.5' 1 · , : , , TRUE TOOL MEASURED DRIFT VERTICAL DEVIATION DRIFT · RUNS ' DEPTH ANGLE DEPTH· COURSE DIRECTION 1.0261 26~' 9586 49 49 96 N66E 1037.9 22~' 9695 51 45 16 N56E 9. · 10417 2~° 9730 87 13 93 N56E · 10754 16½° 10053 99 95 71 N38E · ~3x' 10175 54 2.9 18 10879 ~ 11019 13;5' '10311 67 32 68 N37E · 11126 14'¼' 10415 38 .26 34 N37E 11551 14~' 10827 30 104 61 N37E CLOSUPG N~ $ °~ 4'E--80,~ · · · l~or'm ~o. P--.4 tR.,~d'. 9-30-6'1 STATE OF ( ~KA OIL AND GAS CONSERVATION COMMITTEE .. SUBMIT IN DUPLICATE I~;?~.E DESIGNATION AND S~IAL NO. ~. 14 ZOI~ 8. L~IT,F.~Z OR LEASE N.~E MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS WELL WELL OTHER N.~dV~E OF OPE~R~kTOR Standard Oil Company of California 3. ADDRESS OF OPEI~ATOR 3LOGICAL S1 P. 0. Box 7-839 Anchora~e~ Alaska 4. LOCATION OF WE&J. Surface Loc: 67.25' North and 1,889.11' West of the SE corner of Section 33, TSN, R~,7, SB6~! Final BHL:~/1,727 North and 2,519 East of the S~ corner of Section 34, TSN, R~g, SB6~,I ~.wE~S°ld° t n~xo. Creek 10. FIF-~ P~.XD POOL. OR ~VILDGAT 11. SEC.. Z.. R_. M.. (BOSOM HO~ 0~~ Sec. 34, TSN, R9W, SB~ 12. P]~%MIT NO. 71-21 13. REPORT TOTAL DEPTH AT F~ND OF MONTH. CI4_A_~GF~ 1.%1 HOLE SIZe. CASING ~ C~nNG'JOB~'CL~I~ ~ SET ~ VOL~ USED. P~ORATIONS. ~TS ~ ~SULTS. FISHING JO~. J~ L~ HO~ ~D[~-~~D~O~ ' A~ ~Y O~R SI'GNIFIC~T ~G~ ~ HO~ CO~ITIONS. 'DEC~ER 1 31, 1971 jAN 7 t97 · ·~ ~.1,~ ~''' t with 3/4~ CFR2. Displaced with 25 cu ft. water ahead of 422 cu ft. of mud. Good circulation. ReleaSed fish. Pulled to 10,470'. Backscuttled. D~n squeezed usi~ hesitation method to final pressure of '1,750 psi. Ran in hole with bit. Tagged top of cement at 10,898'. Cleaned out cement to 10,930'. Rennin op~ ended to 10,925'. Cemented with 65 ex. Class "G" cement with 3/4% CFR2 and sand. Displaced with 426 cu ft. of mud.~ Pulled to 10,455'. Backscuttled.'~[ D~n squeezed using hesitation method to final pressure of 2,000 psi. He~ 1 hour. Tagged t~ of plug 10,805'. Fish left'hole consisted of 6" bit, r~rl 4 3/4"x 10' lead collar,,stabilizer, x-over sub:, ~ 3/4"x 26' monel collar, ~f-~ ~ stabilizer, 19 - 4 3/4 x 559' collars, and 3' J releasing sub. Total fis~ Top at 10,937' and bottom at 11,547'. [ [-4 ~.~..~*~. s- n, · - ' ' ' . Ran ~na- Drill f)8 from 10,805' to 10,834'. Directionally drilled 6" hole~g. . 10,834' to 11,551'. ~--~ Dee. 14- 18~ 1971 V~_..~ .... I.--~ Ran Schlumberger Dual Induction Laterolog, Borehole Compensated Sonic, 4 - ~.'~ ....... High Resolution Dipmeter. Conditioned mud for liner. Ran 1,266' of 5" liner. Bottom at 11,549' and top at 10,283'. Cemented with 175 ex. Class "G" cement with 3/4% ~R2. Displaced with 582 cu ft. of mud. Bun~ed plug with 2,000 psi. Good circulation through out cementing. Pulled to 10,280' and d~,n squeezed to final pressure of ~,000 psi. Backscuttled. Ran Schlumberger Cement Bond Log Ga~mma R~, Neut=o~7~log.zz. Tested liner la~ to 2.750 nn~ C._ ~ "*~:l-l~'_ _- . ~-:sR'i'_ _9~'7 · - ..... '. ~-~t ...... ' , ' ', ' - NOTE--Report on this form ~s required for each calendar month, regardless of the status of operations, an¢ must ~ file~ in duplicatt with the Divisio, of Mines & Minerals ~y the 15th of the suCceeding month, unless othe~ise directed. Dec. OIL AND GAS CONSERVATION COMMITTEE ' MONTHLY REPORT OF DRILLING~-"i x [~ AND WORKOVER OPERATIONS} ;:i~! ~' ~ ~...APt SUA'iEP,,IC'A/.~'COD~E 50-133-20231 ~ ~ 28990~ ?.~iA~, A~.~E O~ TRIBE ~. L~'IT,FA~ OH LEASE C:~:~se~on Di~si m Soldo~na Creek .~.ncf~,~'.~.~. Ala~b S~ 13-34 Swanuon ~iver n. szc.. T., ~., M., (BOSOM ~0~ 0~~ See. 36, TSN, R9W, 1~. P~IIT ~O. 71-21 WELL wELL 2. NA.ME OF OPE, R.A, TOR Standard 0il Co. any of California 3. ADDRESS OF OPERR.~TOR P. 0. Box 7-839 Anchorasq Alaska 4. LOCATION OF Surface Loc: 67.25' North and 1,889.11' West of the SE Corner of Section 33, TSN, RgW, SB&M Final BHL: 1,727' North and 2,519'East of the SW corner of Section 34, T8N, R9W, SB&/{ REPORT TOTAL DEiPTH AT F--ND OF MO~'X]-I. CtLA. NGES IN HOLE SIZE. CASING A-~I)C~IENTING JOBS INCLUDING DEPTH SET ~N~ VOL~ USED. P~O~TIONS. ~TS ~%~ ~SULTS. FISHING JO~. J~K LN HO~ ~ND SIDE-~CKED HOLE ~D ~'Y O~ SIGNIFIC~T ~~ ~ HO~ ~ITIONS. 19-26, 1971 , ~ - ii, Ran Schlumberger 3 5/8" Hyper-jet carrier guns and perforated following intervals with 4 - 1/2" hole~per foot; 11,290' - 11,302', 11,310' - 11,328', 11,341 - 11,352' 11,362' - 11,400, and 11,414' - 11,445'. Ran in hole with 5" casing scraper to 11,503'. Layed down 3 1/2" drill pipe. Picked up 1,098' 2 3/8"tubing and 10,080' 3 1/2" tubing and down hole production jewelry. Landed tubing. Removed BOPE. Installed X-mas tree tested to 5,000 'psi. Test okay. Displaced tubing with lease crude. Set packers. Rig released 11:00 A.M. December 23, 1971. JAN 1 7 'DIVISION OF OiL AND r' ~ NOTE--Report on this form ~s featured for each caienaar moron, regardless ~f. the status o~' o.P~ations, an~ must filed in ..duplica~ . . with the Division of Mines & Minerals by the lSth of the succeeding month, unless-otbe~ise dire.ed. . . No. STATE OF ALASKA OIL AND GAS CONSERVATION COt~AI~EE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS SUBMIT IN DUPLICATE APl NU.MERICAI- CODE 50-133-20231 6. LEASE DES'.GNAT1ON AND SEHIAL A-028990 i. ?. IF INDIAN, ALOTT]EE OH TRIBE OZL [--~ CAS ~'~;LL ~LL OTHER 2. N~E OF OP~TOR 8. L~IT,F.~I OR LEASE N~E Standard 0il Company of California Soldotna Creek ~ ~DRESS OF OPE~TOR P. O. Box 7-839, Anchorage, Alaska SCU 13-34 4. ~CA~ON OF W~ 10. 67.25' North and 1889.11' West of the SE corner of Sec. 33, T-8-N, R-9-W, SB&M. Prop. BHC: Approx. 1800' North and 950' East of SW corner of Sec. 34, T-8-N, R-9-W, SB&M. FIF-~.n A.ND POOL. OR WILDC.&T Swanson River Field II. SEC.. T., R., .M.. (BO~O.M HOLE sO~UTv~. ection 34, T-8-N, SB&M 12. PEI:LMIT NO. 7-21 13. REPORT TOTAL DEPTH AT END OF MON]~it, CHA~N'GES IN HOLE SIZE, CASING A1VD C~IF~NTING JOBS INCLUDING DEPTH SET A/%q) VOLLrMES USED, PEI%FO~TIONS. ~'ESTS A-N~D F~ESULTS. FISHING JOB~. JU/~K LN HOLE A~ND SIDE-TI~ACKY_/) HOLE Au'qD A/~Y OTI~ER SIGNIFICANT CttANGES IN HOL~ CONT)ITIONS. NOV. R-9-W, NOV. NOVEMBER 1-30, 1971 NOV. NOV. Nov. 1-7, 1971: Worked through tight spots 5583' to 8296' and to 11,014'. Ran 7" casing: stopped at 10,490'. conditioned hole for Cemented casing in stages. Nipple.d..~u~p_.BOPE, removed rotati__ng head. Layed down 4 1/2" drill pipe!~nd picked up 3 1/2" pi~e, preparatory to drilling 6" hole 8-9, 1971' - .... ' .... Cleaned out cement and ran Schlumberger cement bond log 10,390' to 9250' 10 and 11, 1971: Began cleaning out in old 9 7/8" hole with 6" bit at 10,400'. No indi- cation in old hole below 10,550'; sidetracked at this point. ~rilled ahead in new 6" hole to 10,710'. 12-22, 1971: Drilled to 11,547' . Stuck pipe at 11,547'---30 feet from proposed TD 23-30, 1971: ~ ' Fishing for pipe stuck @ 11,547'. Ran 12 string shots and free points. Backed off at 10,878'~ top of. drill collars. Latched onto fish and jarred while spotting diesel.' Ran ~re~ Point and string shot at 10,937'. Retrieved two drill collars 10,878' to 10,937' Continuing jarring and spotting oil. ' casing two 14. 1 hereby cer~'f~ t i ~ '£ 'ego',;o~9~,~s ~_ "d ~ ' ' s,~~'¢~~(' ~~~istrict Superintende~ December '7, 1971 _ . ~.~;~~o ~ ,, NOTE--Report on this form ~s required for each calendar month, regardless of the status of operations, anO must ~ filea in duplicate with the Division of Mines & Minerals by the 15th of the succeeding month, unless othe~i~ directed. 1"cfm No, P---4 r~cv. ,-~.e7 STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUBMIT LN' DUPLICATE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1, W£LL WELL OTHER 2. NAME OF OPER. ATOR Standard Oil Company of California 3. ADDRESS OF OPEP. ATOR P. 0. Box 7-839, Anchorage, ...Alaska 4. LOCATION OF WELL 67' North and 1889.11' West of the SE corner of Sec. 33, T-8-N, R-9-W, SB&M. Prop. BHL: Aprx. 1800' North and 950' East of SW corner of SeC, 34, T-8-N, R-9-W, SB&M. 5-~PI NUAIER1CA.L CODE 50-133-20231 LEASE DES:GNATION AND SEEIAL NC). A-028990 7. IF INDIA)~', ALOTTEE O]{ TRIBE NAME 8. L."N1T,F.~:iAI OR LEASE Nbd~[E Soldotna Creek 9. %VELJ. NO SCU 13-34 10. FLELD A-ND POOL. OR WILDCAT Swanson River Field 11. SEC.. T.. R.. M.. (BOq~FO.M O _aiCCT .n~ bectzon 34, T-8-N,R-9-W, SB&M 12. PEHN/IT NO. 7-21 13. REPORT TOTAL DEPTH AT END OF MONTH, CHA. NGES IN HOLE SIZE, CASING A/N/) CE,'~IENTING JOBS INCLUDING DEPTH SET A/%q) VOLLrdTES USED, PEILFORJkTIONS, 7-ESTS ~ tAESULTS. FISHING JOINS, JUNK LN HOL.E A-ND SIDE-TIq~kCKED HOLE A_ND ANY OTHER SIGNIFICA/~T CH_A_NGF. S IN HOLE CO~rDITIONS, OCTOBER 1-31, 1971 Oct. 1 and 2, 1971"/ Directionally drilled 9 7/8" hole to 10,817'. Ran Schlumberger IES Log for correlation @. 10,817' . Log stopped at 10,200' . Drilled ahead to 10,968' . Mud weight 97 PCF. OCt. 3 and. 4, 1971: , Shut well in while drilling a.t ll,0~4'due to gain in mud pits. Had pressure build up of 60# on annulus. Opened choke line and began to pump into well @ 30' stroke~ per min. Lost circulation. Spotted 40 bbls. of 97# mud with LCM. added. Tripped out of hole and back in to 10 3/4" csg:~shoe at 3,063'. Could not keep hole full. Attempted to regain circulation with mud & LCM. Oct. 5-8, 1971: Continued attempts to regain circulation with LCM. NQ success. Ran in and cleaned out bridge at 5440~. Well shut in. Ran temper.ature ...... survey & radio- active bead survey. Estimate lost circulation zone 3400' to 50' below shoe of 10 3/4" csg. Flow moving past bit at 5440' from water sand below. Oct. 9-.13, 1971: Mixed mud to kill flow. Installed rotating head on hydril to enable reaming/ drilling to bottom under small surface pressure ranging from 50 tb 250 psi. Oct. 14-23, 1971: Reaming hole and drilling bridges 5440' to 9167'. Gradually built up mud weight to 96 PCF and continued adding LCM. Lost circulation zone healed and water flow stopped. Oct. 23-27, 1971: Stuck drill pipe while cleaning out ,at 9167'. Backed off and recovered' fish. Mud stabilized at 96 PCF. Oct. 27-31, 1971: Cleaned out bridges. Circulate and condition mud to 11,6i~"' TD. Working 'through ~.ight spots preparatory to running 7" casing. Coal sloughing and plugging_~.return line from ro~at'i~g head, .............. · ...... TITL~ . Dis tri_c._t S up _e~r i_n t e n d~llq: smmm__~__~~ December 7, 1971_ ~"'---- ~~~ - ............. /~'-~ ii~ ~ .... " NOTE~Report on this form Js required for each calendar month, regardless of Lhe staLus of operations, and must be filed in dupli£ate with the Division of Mines & Minerals by the 15Lb of the succeeding month, unless otherwise directed. UNITED STATES ~ DEPARTMENT OF THE INTERIOr~ GEOLOGICAL SURVEY ~"orm approved. Budget Bureau No. 42-R356.5. L,,,,,, o,:-,-,c~-_~__n.~_h_._°.F__a__cJ_._e_ ........... N A-028990 LEASE UMBER' = ............................... U.,T ......... _S.__o_.l__.d__9__t___n__a_.._.C..r_ _ .e__e__k_ LESSEE'S MONTHLY REPORT OF OPERATIONS The followin~ is a correct report of operations and productio~ (inch, din~ drillin~ and producin~ wells) for the ,nonth of ....... _~_.o___v__e___m__b__.e._r.. ............... ,19_.7_.1._, ............................................................................ .g~ent'saddress P.O. Box 7-839 ~ Standard~il~ Co of Calif .................................................................. uompany ..... -._2=__3 ......... :_ _..~_ __.=~_._: ..... :='_ ................ · Anchorage, Alaska ............................................................................................. Phone ................................ ~__._2_.7._9__.-__9._.6_6___6. .................. '_ ......... J~ent' s tltl~i-s-t~:-i-cl:---S~pex-i-n~.~_n~e~xt_ Cu. Ft. or GAS G~LLONS OF BAI~RELS Or REMARKS ~EC. AND TWP. ]RANGE WELL DaYs BARRELS OF OIL GRAVITY GASOLINE Wx~r.~ (If (If drilling, depth: if shut down, cause: ~ OY ~ NO. Pao~vcs. (In thousands) date and result of test for gasoline RECOVERED none, so state) content of ga~s) BHC 34 SW of SE 8N 9W 13-)4 3 0,, 1 !) 7, % NOV. 1-7, 1971: Wcrke ~ throu Ih tight spot:~ 5513' to 82 )6' and condit:.oned hole for c,.sin,l to 11 014'. Ran 7'" casJ:ng; stopl>ed at ' 0,490'..t Cemented casi] ir stage . Nippled up BOP5, remove~t rotat: ng hea~.. Layed down 4 il/2' drill pipe and Pi. cked up'"3½'' piPe, pr.e'para.tor5, 'to drilling 6'" ho:Le. ' NOv. 6-9, 1971: C]ean..~d out (:ement and ra:~ Scklumberge~ cement' bond .:og ~'6,390' tc 92~0 ' . . ' No~. 10. .... a.:xd 11 ,. ' 9._.7..13 Began ¢ieani~g out in old 9 7/8" hole ~ ith 6" bit at 10,400'. No indic.~tioln ix~ old hole be .ow 10,550'; idetra:ked at this point. Dxill.)d ahea(~ in new 6,, h()le to 10,710 . . NOV. 12-2 !, 1971 D'zill(:d to 1' ,547'. Stuck pipe at 11,5~ 7' - 3( feet rom proposed TE. Nov. 23-3(), 1971 Fishi)~g for t~ipe stuck @. .1,547'. Ran ]2 stri)~g shot~ and free pein' Backe(! off aif 10,878') top of drill collars. L(tched ¢,nto fish and jarre(! while/spotting die ;el. Ran Free Point 6~nd str3.ng shot at 10,93 )'. Ret:'ieved two dr 11 cgllars 1( ,878' t:o 10,927'. Continuing jarri~xg and :potting oil. · NoTE.--There were ...................................... runs or sales of oil; .............................................. M cu. ft. of gas sold; ............................................. runs or sales of gasoline during the month. (Write "no" where applicable.) NOTs.--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the supervisor by thc 6th of the succeeding month, unless otherwise directed by the supervisor. Form 9-329 (January 1950) U.S. GOVERNMENT PRINTING 0FF~C£:19~1--0--729--754 lo, tm No. P--4 R_.wV. STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE /~ONTHLY Rr. PORT OF DRiLLiNG AND WORKOVER OPERATIONS 1. OIL ~ GAS WELL WELL ~ OTHER 2. NA~ME OF OPERJ~TOR Standard Oil Company of California~ WOI ADDRESS OF OPEZR3kTOR P. O. Box 7-839, Anchora~e~ Alaska 99510 LOCATqON OF WELL 67.25' North and 1889.11' West of the SE corner of Sec. 33, T-8-N, R-9-W, SB&M Prop. BHL: Approx. 1800' North and 950' East' of SW corner of Sec. 34, T-8-N, R-9-W, SB&M. AP1 ND~.¢EHICAL CODE 50-133-20231 LEASE DESiGAtA ~--ION AND SERIAl. A-028990 7. IF INDIA]i[, ALOTTEE OR TRIBE NAME 8. L~.'IT,F.adRA.I OR LEASE Soldotna Creek 9. WELL NO. SCU 13-34 10. FIF_J.~ A_N'D POOL. OR WILDCAT Swanson River Field 11. SEC., T.. R., A{.. (BOTTOM HOLE OB,mCT~ Section 34, T-8-N, R--9-W, SB&M 12. PEP-MIT 1%70. 7-21 REPORT TOTAL DEPTH AT END OF MONTH. CF_kNGES Ii~q HOLE SIZE. CASING AND C~WIENTING JOBS INCLUDING DEPTH SET A~N-D VOLIJIVIES USED, PER/~OHATIOATS. TESTS A/krD IR~ESTJLTS, FISHING JOBIS, JLrNK L~T HOLE A_ND SIDE-TI:LACKED HOLE AND ANY OTH~I% SIGNIFICANT CH_JkNGES IN I-IOL~ CONDITIONS. September 1-30, 1971 Directionally drilled 9-7/8" from 5,133-10,768' Ran Dyne Drill ?~2 - 5,481-5,541' #3 - 5,800-5,959' ~4- 6,041-6,255' ?;5- 7,515-7,587' #6 - 8,753-8,832' ~7- 10,261-10,299' 14, ! hereby c~rti£y i~at szomm ~'//& ~'~f~~ ~ District Supt. NOTE--Report on this form is required for each cate.dar month, r egardles~ of with the Division of Mines & Minerals by the 15th of the succeeding month, unless othe~ise directed. UNITED STATES (~ DEPARTMENT Of THE INTERIOR GEOLOGICAL SURVEY Form approved. Budget Burenu No. 42-R356.5. u.o omcE ~__n..c.~_9.~:_.a.F_9- ..... ' ....... LEASE NUMBER A- 0 2 8 9 9 0 u,,T ........ _ _S_ _o_ .%_ d. . _o_ _t___n_.a._. _ _c__ _r__e_ _e_ _ _k. LESSEE'S MONTHLY REPORT OF OPERATIONS The followin~ is a correct report of operations and production (includin6~ drillin~ and producin~ wells) for the month of ...... __O__c_._t_.o__b___e__r__ ................... 19__7_.1._, ............................................................................ ~l~ent's address ................... ?__:.._.Q.:_..B__.o_.x..__.7._-_._8..3__.9_ ............ Company S tar~d-ard~Oi 1. C~_~ £ Ca1 i f ........... :~ ~ ......~":~ ..... ..~-'~::')-3-:, ...... ........................................... ...... : ........... ..... ..... phone ................................... _2__7_9___-__9___6_.6.__6_ ............................ ~lEent' s title __D~f-n£ct._Supe~ir. te~x~Len t ~EC. AND BARREL~ OF OIL GRAVITY GASOLINE WATER (If (If drilling, depth; if shut down, cause; ~ OF ~ TWP. RANaE WELL D*Ys CU. FT. OF GAS GALLONS or BARRELS OF REMARKS NO. Paonl~c~:r~ (IIx thousands) date and result of test for gasoline I;~ECOVERED lloI3e, SO state) content of gas) recc.ver,.~d ~ish. Mud st~bili ~ed at 96; PCF. ',Oct,,. 27~3.1, , 19_71: ~.. 2lee.ned out bri ]ges. Ci~c'ula~e and condition mud to 11,014' TD. qorked ~hrough -ight s.pP..ts pceparatory to.running 7i" casing. Coal ~lo~lghi%g and p lugging ~return line from rotating head. , PAGE 2 o f 2 · . . . _ · NoTE.--There were ...................................... runs or sales of oil; .............................................. M cu. ft. of gas sold; ............................................. runs or sales of gasoline during the month. (Write "no" where applicable.) NoTE.--Rcport on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the supervisor by the 6th of the succeeding month, unless otherwise directed by the supervisor. Form 9-329 (January 1950) U.S. GOVERNMENT PRINTING OFFICE: 1964--0-729-784 UNITED STATES DEPARTMENT OF THE INTERIO,, GEOLOGICAL SURVEY Form approved. Budget Bureau No. 42-R356.5. UNo Omc~- ___ _A_ _n__c_._h 9_r_.a_ 9_ .e_ ......... LEASE ....E. _ A_'-_-_o.__~. ~_9.__9_ fi ............ u,n' ............ .S__o__ !_. _d_ _o_ _ .%_n__.n____C___r_ .e_.e_ k LESSEE'S MONTHLY REPORT OF OPERATIONS i The followin~ is a correct report of operations a~d production (includin~ driIlin~ and producin~ wells) for the montk of ....... _o_.c___t.p._b___e__r._ .................. , m__7_)__, ............................................................................ /J ~ e n t ' s address .................... _P___.____O___._____B__o__x_.___7___-__8___~__9_ .......... .'C o ~ % ~ ~. ~ ~ ~ ~_ ~ _ _~. _ _ _,~_x~.. _ ~ : /~. : ~ ~_ox.~_ . .. .C_ _ _a_ . _]_ . _~.~_ . .............................................. _A.__n__c__h__.o__r...a__g___e__:___.A_l._a...s__k.._a_ ...... o~ enea ....... ~;~ ~,~_:. _jeh_~,,d_£_e~t~r ....... ,~.~.:~ Pkone ................................... _2__7___9.__-_.9_.6.._6__6.. ............................ /l~ent' s title D__i_a_t___r_i_c__t;___$_~_p_e_r£_rt_t_e_a_d__e_n__t ~EC. AND 34 ..... Of" ' Oct. Oct. Oct. Oct. OCt. Oct. Cu. FT. or (]AS BARRELS O¥ OIL (In thousands) er: 1-31 lled 9 hole to on @ 1 . Log s weight '97 'P :F. le dril of '60 ,, 30 str wi th L at 3,0 with ts to bridge ad s 3/4" 1 flow. to bot drill PCF.and flOw s GALLONS OF (]ASOLINE ]{ECOVERED 1971 10,817 opped 11,014' due ~. Opened ~r 'min. Lost c Led..Tri;Ped out ;ould noi LCM. circula 0'. Wel timate BARRELS OF WS~r~ (If none, so state) keep zon wi 1 shut lost ci . Ran t 10,2( REi%~ARI<S (If drilling, depth; if shut down. cause; date and result of test for gasoline content of gas) chlumberger IES 0' . Drilled ahead to gain[in mud pits Had chokeIoine and began to irculat n' Spotted 40 of hole and back in to ole full. Attempted to th LCM. in. Ran rculati¢ Flow reeving past bit ~lled rotating head on ace pres !167'. G · Lost r small surf dgeS 5449' to hued adding LCM · No success. Ran ir temperature survey n zone 3400' to 5C at 5440' from hydril to enable sure ranging from radually built up circulation zone xng NoTE,--There were ...................................... runs or sales of oil; .............................................. M cu. f~. of gas sold; ............................................. runs or sales of g.%soline during the month. (Write "no" where applicable.) NoTr.--Report on this f°r~n is required for each calendar month, regardless of the status of operations, and muss be filed in · duplicate with the supervisor by the 6th of the succeeding month, unless otherwise directed by the supervisor. "~ Form 9-329 ' U.S. GOVERNMENT PRINTING OFFICE: 1964---0-729-784 (January1950) PAGE 1 of 2 r~-v. 9-~-67 STATE ALASKA sum~rr ' ~ AP~ N~E~C~ CODE OIL AND GAS CONSERVATION CO~I~EE 50-133-20231 MONTHLY REPORT OF DRILLING AND WORKOVSR OP[R~TION$ ~-028990 ~RLL WELL .... Standard Oil CmpaW of California, woI Soldotna Creek ADDRESS OF OP~TOR 9. WE~ NO P. O. Box 7-839~ Anchorage, Alaska 99510 67.25~ ~orth and 1889.11~ ~e~t of the 8E corner o~ Swanson R~uer ~e]~ Sec. 33~ ~-8-~ R-9-~, SB~ ~. s~c..,., a..~.. Prop. BHL: ~pprox. 1800~ ~orth and 950~ East corner of Sec. g6, ~-8-~, R-9-~, 8B~. 1~. P~IT ~O. 71-21 REPORT TOTAL DER'TH AT END OF MONTH, CH.A!'¢GF_,S IN HOLE SIZE, CASING A_N'D CE1VIENTING JOBS INCLUDING DEPTH SET A/WI) VOL~ USED, PERFORATIONS. TESTS ANT) RESULTS. FISHING JOB~, JUWI{ LN HOL]g AA~D SIDE-TIR~.C~ HOLE A3q'D A.NY OTI~Et{ SIGNIFICA~T CHJkNGF. B IN HOI.~ CONDITIONS. Well spudded 2:00 am, August 21, 1971. 18" conductor at 70'. Drilled 15" hole to 2622'. Hit bridge at 278'. Reamed and circulated out gravel to 440'. Raised mud viscosity to 120. Hole bridged and started losing partial circulation at 440'. Started pulling out. Worked pipe up to 384'. Pipe stuck at 384' - no circulation. Worked stuck pipe. Ran GO-International string shot. Backed off 9" D.C. at 235'. Pulled out leaving 149' of fish in hole. Ran Bowen jars and bumper sub. Screwed into fish, bumped down and worked loose. Regained circulation. Recovered fish. Reamed and circulated from 370-1,011'. Drilled 15" hole from 2,622-3,110'. Circulated and conditioned hole. Ran and cemented 10-3/4" casing at 3,063'. Cemented in two stages: Stage No. 1 with 1,000 sacks Class "G" cement, and Stage No. 2 through DV collar with 650 sacks Class "G" cement. Outside job using 100 sacks of cement. Installed and tested Class III BOPE. Drilled out cement and cleaned out hole. Drilled 9-7/8" hole from 3,110-4,000'. Ran and oriented Dynadrill No. 1 to 4,077'. Directionally drilling ahead at 5,133'. DI¥I$1ON OF OIL AND GAS AI~ICHORAGR ~ ' ~ k,, ~. ;~.;.'~/~,'. /~"- '~ t D~S September .~C~ 1971 NOTgIReport on this form is required for each calendar month, regardless of the status of operations, an~ must ~ filed in dupli~te with the Division of Mines & Minerals by the [Sth of the succeeding month, unless othe~ise directed. YELL NO. SCU 13'34 couirrY OF SECTION mO. 33 TOHNSHIP 8 N TRACT NO. LOT NO. ~ PROPOSED } ri PRELIMINARY ~ FINAL - LOCAT I ON WELL SURVEY Pro-312 Kenai CITY OF RANGE 9 W E:3 $. 8.;B, & w. rm W.D.m. & W. F! ELD 67.25' North aionq East Section Line from Southeast Corner Section 33~ T 8'N~ R 9 W, S.M. and 1889.11 West at ricnt angle ELEVATION: GROUND , , 128.5 CO~C.RETE HAT DERRICK FLOOR ALTE~N &T[ OR SURVEYED LOCATI O~ DESIGNATION Final NORTH ! I ! I ---+--- {-- ! ' 889. i SOUTH ~ LOC~TIO~ COORDINATES N 22~ 095.922.51 E 2~ 022:971.96 'MOVE Universal transverse .me ~_ca t~or_. Grid) i · , I-'-q ~1 SKETCH OR ~RK8 Surf~c~ ]oc~on ~s on well SCU ~IVISION OF OIL AND GAS ~. BENCti HARK IS: Top of metal rim of well cellar on N. side of well Elev. 128.55 C.C. DIV., ENGR. FILE Plllllla I# SURVEYOR ~. '" DATE Aug ~LI~. ]l~.~: 19]]~ DATE HAINT. SUPT. DATE F'R¢;.312 (25b[,.CDo1-~ ') ALAS~ OIL AND CAS CONSERVATION COI~IITTEE August 16, 1971 5~ 13-34 Pe~t No. 71-21 Standard Oil Company of Califo~a ?. O, Box 7-839 AnehoraEe, Alaska 99510 Enclosed is the approved application for permit ~o drill ~he above referenced ~I, on or about August 16, 1971, at a location in Secttoa 33, Township Range ~, S. H. Well samples and core chips are uot required. A directional survey is required. A re~estered su~¢ey plat ~t be submitted prior to tb~ completion of the well, Hany rivers in Alaska and ~hetr drainage sys~ have been classified impor~t for ~ese ~e~ ~e subject to AS 16.05.870 ~ the regulati~ pr~igated there- ~er (Title y~ ~y be contact~ by ~e ~ibita~ ~di~tor's office, De~rt~t of Fish In ffhe eveat of suspensfo~ or aba~onment pIea~e no~Y this o~fic~ adequately in advance so that we m~y have a ~tness present. Very truly yours, ~ L. Burrell Enclosure cc: Department of Fish and ~m~e ~/o enci, STATE OF ALASKA i~/-~ ~, ~I 50-133-20231 OIL AND GAS CONSERVATION ,COM APPLICATION FOR PERMIT TO D,,ILL, Dc~:PE,' .......... l--'--h---' s~ 1~ ~o2899o DRILL ~ DEEPEN LJ PLU~ UA]H~~ 2 NAME Creek ~. ~u~ ~ 13- 34 P. 0. Box 7-839, Anchorage~ Alaska 99510 /C~=~~~A~UP~'O~'O~W~UC~T 4 uocaw~oNOZW~m ~~ ~ q swanson River a~rf~ee 67.25' North and 1889.11' 'West of SE ~~~- corner 'of Sec. 33~ TSN, R9W, SB&M. section 34 .~p~.opo,~o~.~o~ Approx. 1800' North and 950' East of SW ~~er offS4. T~N. Rqw. ~R.~M TSN, R9W, SB&M 13, ~ISTANCE IN MIL~;S AND DIRECT',~ F.tO~ N~AHE~T TOWN OR POST OFFICE* [ 1~. ADproximatelz I7 miles from Kenai 14. BOND INFORMATION: Nationwide =~pz s~=~et~. ~..o~ ~o. 431581 ~m~=t $150,000 DISTANCE FHOM PROPOSED* ]16. NO. OF ACR~ IN LEASE '17. NO. ACRES ASSIGNED 15, ~.op~a~Y OR cs~SS ~W~. ~. 7000 ' I 2400 40 * (Ai~o tO nearest drig. unit. if ~nY) ~ 18. DISTANCE FROM PROPOSED LOCA~ON* ~19. PROPOS~ D~-- ' 20. ROTARY OR CABLE 'FOOLS TO NEAREST %YELL DnlLI.,ING, COMPLETe. / OR APPLIED FOR. ~. 1174 ' [ 11,800 ' Rotary 21. ELEVATIONS (Show whether DF. RT. C~, etc.} ~, A~PROM, DATE WOEK WILL START* Approximately 130', ground level 8-27-71 ~3. ~IOPOSED CASING AND CE?~IENTING SIZE OF HOLE SiZE OF CASING~ %'EIGHT PER Fqp~ .j _9~ADE lS~LNG D~ ADDrOX 18~' 18" i 116 ~~~ 80' _.. no cement ....... .... ~,.~%. ~~~~_~, s oo ' z5o. Section 2060 (1) lB) Reason for deviation. To avoid AU~ 12 79/1 disturbing additional natural features in the Kenai Moose Range. Well location previously approved by Division of Oil & Gas (See Conser- vation Order No. 106). UN ABOVE $t~AiT~ I)ESCRIBE t~lqOPOSEID PROGE,A2~: If proposal ts to deepen or plug back. give data on present producllve =one and propo'sed new productive zone. If in'olx~sal is to dr'ill or deepen direct.onally, give pertinent, data on ~ubsurface locations and rneas,A~e~ and true ye?rice! d,e~th.s. Gl~e )Di~m-o%~,, preventer p~'~gram. 8-/7~c 71 OATm _ 'mTL~: Dist. Supt. (This space for St~tte of£lce use} CONI)ITI@NS OF A.P}~ROVY~L, IF ANY: SANIPL~,~ AND COIIE CHIPS ~E~IU'IF~*~I3 YEs ~_.NO_=__ EI!itII,>%Ti'IONAL SU]-IVEY I~Q~ OTHF__,R F-,.EQU IB. EMENTS: SEE TRANb'~ITTAL LETTER A.,'.I. Nl/NIlia%ICAJ~ CODI~ I i · I · I · I · S.C.U. 13-34 kOC:,~i ~"" OF j4 SWANSON RIVER FIELD ' °'4 \ KENAI AL.A~iK .... · ~ .,. ~ ~.~;~,. ~ ....~. ~.~ ~ -__~ -__ _ m~_~ ,..:~ . ~~~ ~. ~;~. .~~.,., _~ ' r' , *~ U !3 34 ~FIELD_ =.L/LO..AT,O,, NO-. S C - iRY/ARD °' '"' DEPTH_!!,aOO-M~.nOD O~ PZO3UCTION~19 or 6/~ M~. -~:"-~r~ ~z-V'~iO0 200/ 35~11~ FO~ ST~N'i_' NO ~IN~ tar face --uires: Swanson River . ..DATF April_ .30, 1971 ESTIMATED SPUD F'CTIk~,ATED qU~,F'. P.~ESSURF 3000 INJ No PRODUCER Yes =l/afar SfrM=: Design based on mud densRy 97~]bs./cu' ff. and above max. sur[. pressure TOTAL .~_qui r es: PS; Gro:s Foofeg~ AFl Size - Weight Grade Threads Coupling Computer Design For: +80' 18 Heavy Wall Line Pipe '[hisWetl [-[ 2900'+ 10-3/4" 40. 50# K-55 8rd ST&C Standard Design For Field U1 Baker Model "G" circulating differential fill-up shoe WellNo. · E] and collar and a Baker Model "J" sta~e cementing Max. Driff~ng[e 30 o · collar. Also requires e'!even 10-3/4 x 15" lace over- the-collar centralizers and one stop ring. RECEIVED 80' 7" 29# N-80 Buttress 4,120' 7" 235 N-80 Buttress 2,500' 7" 26# N-80 . Buttress 2,100' 7" 26# P-110 8rd 3,000' 7" 29# P-110- 8rd 1,800' AUG i 2 197! ~l¥1~ggN OF OIL AND ~i.A$. LT.&C (cot~,~¢%~'~ 29# LT&C N L8rd) 1 - 7"' pup joint 29# P-110 8rd LT&C and 1 x-over, L8rd pin with Buttress box. - Baker Model-"G" circulating differential fill-up collar and 7" Model "J" stage cementing collar. 9-7/8" lace over-the-collar centralizers 'and one 7" 26# N-80 7" shoe and Klso need 15 stop ring. or P-110 7" - 7" x ~'ING '( ,- 5000 Z41TiZED} H=A'D:Tcp Conn.. PSI CWP. Boffom Conn. 10-3/4" sow 10"-5000~ API RJ Flanged 2-2 1 screwed 3000~ OWG valve and 1 scotch screwed nipple. .oufle,~s Feet 500.0# :SI CWP. 8=ffam Ccnn~_..~0"- 5000~ TopCona. 6"-50009 API RJ Flanged lypeSuspension Cosasco, 3%_" EUE down, 2-7/8" :' "Bottom Next Requires': APl Ske WeTghf Grade Threads ~__h. er Equipment: API RJ Flanged 2-2 ,,. Flanged EUE .up. Bored for 2½" Cosas~o plug. .Type Remarks (Cro~s-overs, ~,c.) 11,500'+ 3%"0. D. 9.3# -.. 7-'2%" Camco Packers: One 2-7/.8" x Two 2-~/8" X -~ackers . 4 Camco 2.-7/8" "C" 2-7/8 .... S" nipples. N-80 8rd EUE- _ouHefs MM or MMA mandrels and 15 x-overs, 3%" x 2-7/8". 7" 29# wireline set prod'uction packer. .7". 29# retrievable differential pressure set s le eves, -1 Camco 2 -'7/8" "'D" 5nlpplOOO-'f~e' & 20 tis 3" USI Safomatic flang.ed, ~ i n 9 Catcher z=ker with . ZMAS iREF " l'~b]ng Beans 2- 2 ~sing Beans 2- 2 Sluing Box ,: UMP: "LDDS: Gra ;NGUNIT. APi Size ~ wt. ,, 5OO0~API 5000~API Csg. Size " __.'~Vf. Install Type v4fh _ "stroke at Other F~¢~g~ ..... PSi CWP. Dw9. No- - Alaska District AB-I. 9 RJ -Flq_,TyF~ 1-2 ,, 5000~Willis Tvpe I Flow RJ F ! ~ -TyF=_ " ~r~. _ PSI CWP. Dwg. No__~ .Type. Polished Rod "z ~' .Type af , ": ~_ . . ' Of,-- *'; ~~ Of----. Type_ _Max. S~rake__ "qet at, ' Stroke and ~Ha~or ..... H~ .Remarks_ . B e a n .Type .Type 'Lonc # ~epar'eo gy .,// . W. R. TINKER III Jo J. PROPOSAL FOR WELL OPERATIONS PRO-316-1 DRILLING PROGRAM FIELD: Swanson River PROPERTY AND WELL NO.: Soldotna Creek Unit 13-34 SURFACE LOCATION: Approximately 2000' West and 340' North of the Southeast corner of Section 33; T-8-N; R-9-W; SB&M (Well SCU 34-33 pad) BOTTOM HOLE LOCATION, Target Base Hemlock #5 Sand (H-4 Point): Approximately 1800' North and 950' East of the Southwest corner of Section 34; T-8-N; R-9-W; SB&M (±3150' deviation N60°E). ELEVATION: ! Approximately 130 ~ ground level. BLOWOUT PREVENTION CONSIDERATIONS: 1. Potential Problems: Gas: Gas sands may be ~nc'ountered at any depth below the shoe of the surface pipe. No gas entries were reported while drilling wells SCU 34-33, 14-34, 43-33 and SRU 12-34 using 97-98 pcf mud. Gas entries can be a problem on trips and bottoms up must be carefully watched. Also, care must be exercised whil~ drilling coal beds. If thick beds are penetrated, reduce drilling rate and circulate bottoms up to remove gas. Lost Circulation: Lost circulation occurred at SCU 14-34 at 2600' while opening hole with '80 pcf mud. No lost circulation was reported at SCU 34-33, 43-33, 24-34, or SRU 12-34. Water. ~_ntry: Water entries occurred while drilling SCU 24-34. A 50 barrel entry occurred while drilling at 9355' with 93 pcf mud. It was also necessary to shut-in SCU 24-34 at 9880' with 95 pcf mud in the hole. Drill pipe pressure was 350 psig and casing pressure was 400 psig. The mud weight was raised to 97-98 pcf, and the well was drilled to T.D. without further incident. No entries were reported while drilling SCU 14--34, 43-33, 34-33, or SRU 12-34 with 97-98 pcf mud. PROPOSAL FOR WELL Oi(~(ATIONS PRO-316-1 ~ DRILLING PROGRAM, WELL SCU 13-34 Page 2 BLOWOUT PREVENTION CONSIDERATIONS (CONT'D.) 1. Potential Problems (Cont'd.) Precautions: Any kicks should be handled by our normal procedures. Drilling crews should be made aware of these pro- cedures. Care should be exercised at all times, but especially not to hydraulic the formation and lose circulation while running in the hole nor swab the hole while pulling. 2. Maximum anticipated formation pressure: 5500 psig. 3. Maximum anticipated surface pressure: BLOWOUT PREVENTION EQUIPMENT: 1. As per "Operating Instructions D-17." 2. Class III on 10-3/4" and 7" casing See Figures 1 and 2 for details. 3000 psig. .RECE VFD. .AUG ~.ll¥1~i(j~ 0~; Oil. AND GA~ (10"-5000 psig). OBJECTIVES: Hemlock 1-5 sands, Target base Hemlock #5 sand Estimated Estimated Markers: Drilled Depth Vertical Depth H-1 11,400' 10,590' H-4 11,600' 10,745' T.D. 11,800' 10,930' or H-4 point. Estimated Sub-Sea Depth -10,460' -10,615' -10,800' WELL SCU 13- 34 PROGRAM ... Prior to spud, run Gyro surveys in SCU 34-33 and 343-33. 1. Drive 18" conductor pipe to 80' or as deep as possible while rigging up. 2. Drill a 15" hole to 2885'. Maintain drilling fluid as per attached Drilling Fluid Program. 3. Run 2885' of 10-3/4" O.D. 40.5#/ft. K-55 8rd ST&C casing and cement as follows: a. Use differential fill-up shoe and differen- tial fill-up collar one joint up. Run stage collar at approximately 1270'. b. Lock bottom five joints of casing including mill collars. c. Centralize casing above shoe and stage collar. d. If cement returns are not received at the surface, do a top job. e. Pre-mix cement with 3/4% of CFR-2. Treat last 400 sacks through the shoe with 3% calcium chloride. 4. Cut off 10-3,/4", 40.5#/ft. K-55 casing 36" below the top of the cellar (ground level) to allow the top flange of the tubing head to be above ground level after completion. 5. Install 10"-5000# top flange 10-3/4" SOW casing head. Test welded lap to 2500 psig. 6. Install and test Class III, 10"-5000~ BOPE as per attached Figure ].0 and test with clear water as per Operating Instructions D-17 to 2500 psig. 7. Drill out cement in 10-3/4" casing with a 9-7,/8" bit to within 10' of the shoe. Pressure test the casing to not over 2500 psig. If test is OK, drill out shoe. 8. Drill a 9-7/8" hole to 11,800', T.D. , as follows: a. Follow mud characteristics as outlined on the attached mud program. Note change at 6000'. b. Take single shot surveys from 300' to 4700' , KOP, a minimum of every 480'. Should con- ditions warrant, reduce survey interval to every 240' or less. c. Beginning at approximately 4700' , KOP, build 3°/100' hole angle-to a maximum of 30©. Along course N60°E, deviation is 3150'. Target is base of Hemlock #5 sand at a loca- tion 1800~ North and 950' East of the South- west cOrner of Section 34; T-8-N; R-9-W. Directional program to be furnished. Verti- cal depth at target is 10,745'. Sub-sea depth (using elevation of 130') is -10,615'. Lead well for right-hand turn. 9. At T.D., condition hole for logs. Take 1/2 gal- lon sample of drilling fluid prior to pulling for logs. Run and tape Schlumberger logs (2"=100' and 5"=100' scales) as follows: a. Dual-Induction-Laterolog from T.D. to shoe of the 10-3/4" casing. Linear scale 2"=100'; logarithmic scale 5"=100' . R VED b. BHC Sonic log and four-arm HR dipmeter from T.D. to the shoe of the 10-3/4" casing. 10. Ran 7" casing as follows: a. Bottom 3000' (11,800'-8800') 29#, P-110, L,8R,LT&C Include marker Jt. 29#, P-110, L8r, LT&C ±10' Long. Next Next Next Top TOTAL 2100' (8800'-6700') 26#, P-110 L,8R,LT&C 2500' (6700'-4200') 26#, N-80 Buttress Requires x-over on bottom L8R to Buttress. 4120' (4120'-80') 23# N-80 Buttress 80' (80'-0') 29# N-80 Buttress 11,800' b. Centralize bottom 700' and above stage collar. c. Run 7" Baker Model "G" circulating differential fill-up ~hoe and 7" collar, and Model "J" stage cementing collar at approximately 7500' (determine after log run). d. Run marker joint near top of Hemlock. e. Cement in two stages as follows (use bottom wiper-plug). 1o Through the shoe with sufficient cement pre-mixed with 3,/4% CFR-2 to reach 9500' . Page 3 10. Cont'd. e. Con t ' d. 2. Through stage collar with sufficient cement to reach 5200'. 11. Remove BOPE and land 7" casing. Cut off 7" casing. Install 5000# tubing head and test secondary pack-off to 2500 psi. Install 10" 5000# BOPE and test to 4000 psi (use donut and Cosasco plug). 12. Drill out cement to below stage collar and pressure 7" oasing to 2500 psi to insure collar is closed. 13. Drill and clean out cement to below productive sands. Run Gamma Ray-Neutron Log 1000'± from effective depth to above top of Hemlock Zone. Run variable density CBL from effective depth to top of cement above DV collar. 14. Obtain W.SoO, above zone: If CBL looks good at the W.S.O. depth, consider foregoing test. 15. Perforate with centralized guns selected intervals for production. Run casing scraoer and scrape perforations. Set wireline packer above lower most productive sand. 16. Run and Hydrotest approximately 11,500' of 3%" 9.3~ N,80 EUE 8RD tubing with hydraulic set packer above perforations; Camco MM gas lift mandrels are to be installed at 1800', 3300', 4650', 5800', 6800', 7625', and 8300'. 17. Remove BOPE and install x-mas tree; test tree to 5000 psi. Displace drilling fluid down annulus and out tubing with lease crude oil. 18. Set packer and release rig. Place well on production. /~[~R. TINKER III Mr. W. H. Fairfi ~d.~,.~ Mr. J. W. Walker?; DRILLING FLUID PROGRAM SCU 13-34 SOLDOTNA CREEK UNIT SWANSON RIVER FIELD BASIC DRILLING FLUID SYSTEM Medium treated lignosulfonate mud. OPTIMUM DRILLING FLUID PROPERTIES Mud Property (Vertical Depths) 0-2885' RECE!¥ED pl¥1$101~ OF OIL AND ~A~ ANCHORAG~ 2885 ~-G000 ~ GO00 "-~. D. Weight - pcf Viscosity - sec/qt. , API Fluid loss - CC, API Plastic ViscoSity - CPS 2 Yield Point - lb/100 ft Gel- lb/100 ft2 - 10 min PH Calcium- PPM Solids content- % vol. Diesel content- % VOlo Salvaged mud with gel and cellex added as required. 72-80 93-98 40-60 43-48 7-10 4-7 10-20 20-30 5-10 8-12 10 max 10 max 8.5 - 9.0 8.5 - 10 50 max 8-12 10-18 5-8 6-8 REMARKS: 1. Drill top hole to 2885'_+ with salvaged mud, if available. Run centrifuge backwards to reduce mud weight as required. 2. Convert top hole mud to gel mud while drilling from 2885' to 6000'. At 6000', increase weight and have mud properties as listed in right hand column at 7000'. Run centrifuge normally below 6000'. 3. Use medium treated lignosulfonate mud below 6000'. Limit dry job to 20 sacks of barite or as directed by Drilling Foreman. 5. Maintain an adequate supply of lost circulation material at the rig. 6. Make a High Pressure - High Temperature Fluid Loss determination every third day. Make fluid loss tests at estimated bottom hole temperature of !70°F. 7. Maintain total hardness under 100 ppm and report all versenate titration as (ppm) CaCO 3' 8. Below 8000' (vertical depth), keep mud weight between 97 and 98 Def. 9. Maintain hydraulic.program as directed by SOCO Drilling Foeman. 'Phis program_requires a minimum operating pressure of 2750 psig using 5%" lines. Minimum output through a 9-7/8" bit to T.Do is 350 gallons per minute o STATE OF ALASKA DEPARTHENT OF NATURAL RESOURCES DIVISION OF OIL AND GAS Alaska Oil and Gas Conservation Committee 3001 Porcupine Drive Re: THE APPLICATION OF STANDARD ) OIL COMPANY OF CALIFORNIA for an ) exception to Conservation Order ) No. 8 to permit the drilling and ) completion of an oil well on a ) 40-acre spacing pattern in the ) Swanson River Field ) Conservation Order No. 106 Swanson River Field June 23, 1971 IT APPEARING THAT: 1. The standard Oil Company of California submitted a request dated May 18, 1971 for an exception to Conservation Order No. 8 permitting an 80-acre well spacing pattern, to permit the drilling and completion of a single directional oil well, Soldotna Creek Unit No. 13-34, in the Northwest 1/4 of the Southwest 1/4 of Section 34, Township 8 North, Range 9 West, S.M., on a 40-acre pattern. 2. Standard Oil Company of California is the only operator affected by the requested order. 3. Notice of hearing on the request was published in the Anchorage Daily News on June 5, 1971, pursuant to Title 11, Alaska Administrative Code, Section 2009, and no protest was received. AND IT FURTHER APPEARING THAT: 1. Swanson River Oil Field is currently being produced under a gas injection pressure maintenance program. 2. Faulting plays a major role in oil accumulation at the Swanson River Field, and faults or portions of some faults are barriers to fluid movement. 3. The geometry and configuration of the present 80-acre spacing pattern with respect to the location of barrier faults and productive limit lines does not allow for adequate reservoir drainage in this area. , 4. A poor areal sweep efficiency for the gas injection oil recovery project exists in the eastern flank of the block between Faults "E" and "F" with the present 80-acre spacing pattern. Conservation Order No. 106 Page 2 June 23, 1971 5. Completion of the proposed SCU No. 13-34 well should allow for increased efficiency for the pro~ect, increased recoverable reserves of oil, and greater ultimate oil recovery. NOW, THEREFORE, IT IS ORDERED THAT: The Standard Oil Company of California be permitted to drill and complete as an oil well the Soldotna Creek Unit No. 13-34 in the Northwest 1/4 of the Southwest 1/4 of Section 34, Township 8 North, Range 9 West, S.M., on a 40-acre pattern. DONE at Anchorage, Alaska, and dated June 23, 1971. Thomas R. Marshall, Jr., Executi~ S'ecretary Alaska Oil and Gas Conservation Committee Concurrence: Homer L. Burrell, Chairman Alaska Oil and Gas Conservation Committee O. k.-Gil~ret'h, Jr., Member ~'~' Alaska Oil and Gas Conservation Committee Lease & Well No CHECK LIST FOR I~EW WELL PERMITS Yes No. Remarks 1. Is well to be locate~ in a defined pool ................. 2. Do statewide rules ai~ply ........................ e Is a registered survey plat attached .................. 4. Is well located prope:r distance from property line ........... 5. ~ well located proper distance from other wells ............ 6. ~s sufficient unded~at~.d 7. Is well to be deviated ......................... 8. Is operator the only 9. Can pemit be appro~'¢ before ten-day wait ............... 10. Does operator have a 11. Is conductor string ~rovided ...................... 12. Is enough cement usc to circulate on conductor and surface ...... 13~¢Jill cement tie in s~rface and intermediate or production strings ~ill cement cover all possible productive horizons ............ 15. Will surface casin~ cover all fresh uater zones ............. 16. Will surface cs~. i~'ternal burse equal~-'.5 17. Will all casin~ ~ive adequate safety 18. ~oes gOP[ have suff~c~en~ pressure rat~n~ ............... Additional Requirements Approval Recommended: .~~' TRM o~¢ KLV , JN., _~ .