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Home My WebLink About181-1451. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Re-Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: ______________________ Development Exploratory 3. Address:Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number):8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 5,700 feet 5,373 feet true vertical 4,971 feet N/A feet Effective Depth measured 5,350 feet See Schematic feet true vertical 4,674 feet See Schematic feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet LS 3-1/2" 9.2# / N-80 5,180' MD 4,530' TVD Tubing (size, grade, measured and true vertical depth)SS 3-1/2" 9.2# / N-80 4,587' MD 4,034' TVD Packers and SSSV (type, measured and true vertical depth)See Schematic See Schematic See Schematic N/A, N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure:N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date:Contact Name: Contact Email: Authorized Title:Contact Phone: 4,760psi 3,090psi 6,870psi 2,029'1,907' Burst Collapse 1,540psi Production Liner 5,686' Casing Structural 4,959'5,686' Conductor Surface Intermediate 20" 13-3/8"2,029' measured TVD 9-5/8" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 181-145 50-133-20348-00-00 3800 Centerpoint Drive, Suite 1400 Anchorage, Alaska 99503 Hilcorp Alaska, LLC N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: FEE 093808, FEE A028142 Kenai/Kenai 5.1 & 6 Gas, Sterling 6 GS Kenai Unit (KU) 34-32 Plugs Junk measured Length 87' measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf MD 87' 140 Size 87' 0 1800 0 750 184 Daniel Taylorr, Optimization Engineer 324-651 Sr Pet Eng:Sr Pet Geo:Sr Res Eng: WINJ WAG 5020 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Noel Nocas, Operations Manager 907-564-5278 N/A dtaylor@hilcorp.com 907-947-8051 p k ft t Fra O s O 6. A G L PG , Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov Digitally signed by Noel Nocas (4361) DN: cn=Noel Nocas (4361) Date: 2025.01.02 13:54:53 - 09'00' Noel Nocas (4361) By Grace Christianson at 9:31 am, Jan 03, 2025 DSR-1/8/25 RBDMS JSB 011525 JSB SFD 3/25/2025BJM 2/4/25 181-154 Page 1/1 Well Name: KEU GS KU 34-32 Report Printed: 12/18/2024WellViewAdmin@hilcorp.com Alaska Weekly Report - Operations Jobs Actual Start Date:12/4/2024 End Date: Report Number 1 Report Start Date 12/4/2024 Report End Date 12/5/2024 Last 24hr Summary PJSM. Permit. PT 1000 PSI. Good. RIH w/ GPT-Spang Jars-2.50" Gauge Ring. Sat down at or near XA sliding sleeve at 4544'. Cannot pass. POOH. Gauge Ring covered in formation sand. RIH w/ 2.49" Tapered Gauge Ring. Sat down at same spot 4544'. POOH. Gauge Ring covered in formation sand. Consult Engineer and Foreman. RDMO. Plan forward: Slickline to drift. Report Number 2 Report Start Date 12/7/2024 Report End Date 12/8/2024 Last 24hr Summary PTW/PJSM, D&T long string W/ 2.50" x 6' DD SD @ 5165' SLM (5184' RKB) tap down fall through to 5222' SLM (5241' RKB)(recovered 3 cups sand) DRIFT TAG - RE LABEL TREE CORRECTLY Field: Kenai Gas Field (KEU KGF) Sundry #: 324-651 State: ALASKA Rig/Service:Permit to Drill (PTD) #:181-154Permit to Drill (PTD) #:181-154 Wellbore API/UWI:50-133-20348-00-00 XA Sliding Sleeve @ 4685 Lease: State/Prov. Country:USA Perforations (MD) (TVD) Angle/Perfs BHP: 379 BHT: 82 3/24/1986 Well Name & Number:KU 34-32 Kenai Gas Field County or Parish:Kenai Pennisula Bureau AK Completion Fluid: Dated Completed: C-1, 5207'-5270', B-3, 4630'-4650' Angle @ KOP and Depth C-1 Sd. 5207'-5270' MD, B-3 Sd. 4630'-4650' XA Sliding Sleeve @ 4544 XA Sliding Sleeve @ 4566 Baker Model A-5 Dual Hydraulic Packer at 4576' Baker Blast Joints 4617'-4667' Otis XN Nipple 4585' Baker Model D Packer with 10.5" SA set at 4726' Baker Model D Packer with 21.35" SA st at 5166' Baker Model D Packer with Millout Ext. At 5350' Approximate cement top 1420' in 9 5/8" Annulus 13 3/8", 61#, K-55 to 2029' 20" Drive Pipe to 88' Cemented Squeeze Holes From 4280' to 4282' tested to 500 psi March 1986. Mule shoe at 5180' 9 5/8", 46#, N-80 Casing at 5686' Otis X Nipple With Plug at 5373' Rotary table to Cameron Dual Tubing Hanger 19.45' 3.5 " tubing tail at 5384' All tubing 3.5" 9.2# N-80 Ima ect Well History File Cove~ Igc XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of. the file. J (~"~ / - J F~'"Well History File Identifier RESCAN DIGITAL DATA [] Color items: [] Diskettes, No. [] Grayscale items: [] Other, No/Type [] Poor Quality Originals: [] Other: NOTES: BY: BEVERLY ROBIN VINCENT~MARIA WINDY Project Proofing OVERSIZED (Scannable) [] Maps: Other items scannable by large scanner OVERSIZED (Non-Scannable) [] Lo_.gs.of various kinds ~ther DATE:~/~ /S/ BY: OBIN VINCENT SHERYL MARIA WINDY DATE: ,~ /SI Scanning Preparation BY: BEVERLY ROBI~SHERYL MARIA WINDY TOTAL PAGES~ ts~ ~ Production Scanning Stage I PAGE COUNT FROM SCANNED FILE: PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: ~/ YES NO Stage 2 IF NO IN STAGE '1, PAGE(S) DISCREPANCIES WERE FOUND: YES NO BY: BEVERLY ROBIN VINCE~MARIA WINDY (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECIAL AI-rENTION I$ REQUIREO ON AN INDIVIDUAl. PAGE BASIS DUE TO QUALITY. GRAYSCALE OR COLOR IMAGES ) RESCANNED BY; BEVERLY ROBIN VINCENT SHERYL MARIA WINDY DATE: Isl General Notes or Comments about this file: Quality Checked (do,c) 12/10/02Rev3N OTScanned,wpd Memorandum State of Alaska Oil and Gas Conservation Commission To: WellFile: ~(3 ~"~.~l(~c~ DATE Cancelled or Expired Permit Action EXAMPLE: Point McIntyre P2-36AXX API# 029-22801-95 Re: This memo will remain at the front of the subject well file. Our adopted conventions for assigning APl numbers, permit numbers and well names did not specifically address expired or cancelled permits. This omission has caused some inconsistencies in the treatment of these kinds of applications for permit to ddll. Operators have asked us to adopt formal procedures for this class of permit application in order to prevent future database disparities. If a permit expires or is cancelled by an operator, the permit number of the subject permit will remain unchanged. The APl number and in some instances the well name reflect the number of preexisting reddlls and or multilaterais in a well. In order to prevent confusing a cancelled or expired permit with an active well or multilateral these case sensitive well identifiers will be changed for expired and cancelled applications for permits to ddll. The APl number for this cancelled or expired permit is modified so the eleven and twelfth digits is 95. The well name for a cancelled or expired permit is modified with an appended xx. These procedures are an addendum to the APl nUmbering methods described in AOGCC staff memorandum "Multi-lateral (weilbore segment) Ddiling Permit Procedures, revised December 29, 1995. AOGCC database has been changed to reflect these changes to this permit. e McMa~ns ' t Statistical Technician September ~0.- 1983 Re~ Permit to Drill, Dear Keith ~ St~asko Production Company~ was issued a Permit to Drill the Simpco Chuit~a No. i on September 29, 1981 and drilling was not commenced within 24 months after the approv&l date, as required under 20 AAC 25.005(k}. Should ~u still desire to drill this well it will ~e necessary tO sub~tt a complete new ap~tlcati~n for a new t~rmit. LCS/,JKT ~lc~I03~D ! AT' I[ooo ' Simasko Production Company P. O. BOX 101515 · ANCHORAGE, ALASKA 99510 · (907) 277-5932 · 274-4591 · TELEX 26-338 March 2, 1983 Re: SIMPCO East Moquawkie ~2 SIMPCO Chuitna, Form 10-403 State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-3192 Attn: Mr. Lonnie C. Smith Commi s s ioner Dear Mr. Smith: Attached please find the completed "Subsequent Reports, Sundry Notices and Reports on Wells" (Form 10-403) as requested by your letter dated February 16, 1983, for the following: SIMPCO Chuitna #1 SIMPCO East Moquawkie 92 Thank you. Sincerely, Koith W. Calderwood Vice President KWC: nk Attachments as stated. RECEIVED Alaska. 0il & Gas Cons, C;ommissior~ Anchorage STATE OF ALASKA SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER 2. Name of Operator Simasko Production Company 3. Address P.O. Box 101515~ Anchorage~ AK 99510 4. Location of Well '600' FWL, 1650' FSL, Section 4, TllN, RllW, S.M. 5. Elevation in feet (indicate KB, DF, etc.) -+225' GR'(est.) 6. Lease Designation and Serial No. None 7. Permit No. 81-145 8. APl Number S0-- 283-20069 9. Unit or Lease Name SIMPC0 Chuitna 10. Well Number 11. Field and Pool WilDCat 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations I-] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other (~'~ ~-'~ Pull Tubing r-I 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). Drilling plans indefinitely suspended. 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Vice President The spa;~l;wf Conditions of Approval, if any: March 2, 1983 By Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ) ) February 16, 1953 Si~asko Production Compa~ p.O. Box 1515 ~es Subsequent Reports, Sundry Notices and Report. s on Wells (Form 1.0-403 ) For the following lasts of' "'Notice of Intention To~" Sundry Notices and Re~ort on Wells (form 10-403) this office does not have on record the "Subsequent Report of~ m defining the action taken on the approved in~ention. Please advise this office by Subsequent Report of the disposition of the inte~tion. ~stJ~Cr/g Ih STATE OF ALASKA ALASKA OIL_AND GAS CONSERVATION COMMISSION SUNDRY )rICES AND REPORTS, )N WELLS DRILLING WELL [] COMPLETED WELL [] OTHER 2. Name of Operator Simasko Production Company 3. Address P.O. Box 1515, Anchorage, AK 99510 4. Location of Well 600' FWL, 1650' FSL, Section 4, TllN, RiJW. S.M. 5. Elevation in feet (indicate KB, DF, etc.) ~225' GR (est.) I 6. Lease Designation and Serial No. , None 7. Permit No. 81-145 8. APl Number 50- 283-20069 9. Unit or Lease Name SIMPCO, Chui tna 10. Well Number 1 11. Field and Pool Wildcat 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing I-'1 Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [~1 Pulling Tubing I-] (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). Additional time has been required to refine the seismic and struCtural interpretation of the prospect area which will further delay s'pudding this well. The same riq will first be us, ed to drill SIMPCO East Mo~uawkie Well No. 2 (Permit No. 81-156); conseouentlu, the anticipated spud date is now Julu 15, 1982. 14. I hereby cer~ue and correct to the best of my knowledge. FEB 4 1982 AlasKa L~,:. Er. EIVED ££8 o 1982 ~8~ Oil & Gas Cons. Comm~.,_._ Signed The space below for Commission use Conditions of Approval, if any: W. R. Ste~£t Title President Approved Approved by ORIG NA]. SIGNED LONXlE C. SIAITII COMMISSIONER Returned By Order of the Commission Date 2/4/82 Form 10-403 Rev. 7-1-80 Submit "intentions" ,n Ir,pi,ca; and "Subsequen! Reports" in Duphce September 29, 1981 Mr. W. R. Stewart, President Stmasko Pro~uction Company P. Oo Box 1515 Anchorage, Alaska 99510 Re~ sIMPCO ChUttna No. 1 Simasko Pro~uction Company Permit No. 81-145 Sure Loc.~ 600~'FWL, 1650~'FSL, Sec 4, T11N, RlIW, SM. Bottomhole Loc.~ S A M E Dear Mr. Stewart Enclosed is the approved application for permit to drill the above referenced well. Well samples and a mud log are not required. An inclination survey is required. If available, a tape containing the digitized log information shall be submitted on all logs for copying except experimenta~ logs, velocity surveys and dipmeter surveys ~ ~.~ny rivers in Alaska and their drainage systems have be.~n classified as important for the. spawning or m£gration of anadromous fish. Operations in these areas are subject to AS 16.50.870 an8 the regulations promulgated thereunder (Title Alaska Administrative Code). Prior to commencing operations you may be contacted by the ~abitat Coordinator~ office, Department of Fish an8 Game. Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Article ? an~ the regulations promulgated thereunder (Title 18, Alaska Administrative Co~e, Chapter 70) and by the Federal ~ater Pollution Control Act, as amended. Prior to Mr. W. R, Stewart SIMPCO Chuttna No. I -2- September 29, 1981 commencing operations you may be of the Department of Environmental ~presentative To aid us in scheduling field work, we 'would appreciate your notifying this office at least 48 hours before the, well is s~dded. ~ would like to be notifie~ so that a representative of the Commission may be present to inspeot the diverter system before the '¢ondu~or shoe is drilled and also to witness testing of blowout preventer equtp~nt before surface casing shoe is drilled. In the event of sus'pen.sion or abandonment, please give this office ade~ate advance notification so that we may have .a witness present. Very ~uly yours, ~. aami 1ton Cbmirman of BY ORDER OF THE CO~EI;SSION Alaska Oil & Gas Conservation Com~ission Enclosure Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o/encl. Simasko Production Company P. O. BOX 1515 · ANCHORAGE, ALASKA 99510 · (907) 277-5932 · 274-4591 · TELEX 26-338 September 21' 1981 Re: SIMPCO Chuitna #1 Application for Permit to Drill Alaska Oil and Gas Conservation Commission State of Alaska 3001 Porcupine Drive Anchorage, AK 99501 Attn.. Mr. Hoyle Hamilton Commissioner Gentlemen: Simasko Production Company hereby makes application for a permit to drill an onshore exploratory well on the west side of Cook Inlet at a location in Section 4' TllN' RllW, S.M. Enclosed in triplicate are the following: (1) Completed and executed Form 10-401, "Permit Permit to Drill". (2) Supplemental Data Sheet attached to the Permit form providing detailed information on casing program, cementing program, drilling fluids, anticipated geology, formation evaluation, and pressure control practices. (3) Proposed Location Plat prepared by F. M. Lindsey & Associates. (4) Blowout Preventor Equipment Drawings for 17 1/2" surface hole and for 12 1/4" and 8 1/2" hole. (5) Surface Facilities Map upon Which existing facilities are indicated together with lease boundaries. Also enclosed is the required fee in the 'amount of $100 00, payable to the State of Alaska, Department of Revenue. ' e This wellsite is located on a fee lease which has been ntered into by and between Cook Inlet Region, Inc., as Lessor, and Simasko Production Company, as Lessee. The wellsite lease Alaska Oil and Gas Conservation Commission September 21, 1981 Page Two contains 8,785 acres and is indicated as "Area II" on the Surface Facilities Map. A Surface Use Agreement has been entered into with Tyonek Native Corporation, owner of the surface estate, covering all surface activities including extraction of gravel and construction of drillpads, roads, and airstrips. As indicated on the executed application form, Simasko Production Company maintains a $200'000 Statewide Blanket Bond from Travelers Indemnity Company bearing Bond No. 148F0140. This bond was submitted to your office on January 12, 1981, We are targeting for a November 1, 1981 spud date on this test and will appreciate your early attention to review of this application. Sincerely, ~~t Pres ido nt WRS/jm Enclosures SEP,? 1 1581 Alaska Oil & Sas COns. C°mrnissio/7 Anchorage STATE OF ALASKA ALASKA £ ~)AND GAS CONSERVATION CC; ~vllSSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL ~ lb. Type of well EXPLORATORY I~ SERVICE [] STRATIGRAPHIC [] . REDRILL i-'] DEVELOPMENT OIL[] SINGLE ZONE [] DEEPEN [] DEVELOPMENT GAS [] MULTIPLE ZONE [] 2. Name of operator ' . Simasko Production Company 3. Address P.O. BOX 1515, Anchoraqe, AK 99510 4. Location of well at surface 9. Unit or lease name 600' FWL, 1650' FSL, Section 4, TllN, RllW, S.M. SIMPCO Chuitna At top of proposed producing interval 10. Well number Straight Hole 1 At total depth 11. Field and pool Wildcat 5. Elevation in feet (indicate KB, DF etc.) I 6: Lease designation and serial no. +-225 GR {Est. toDo sheet)J None 12. Bond information (see 20 AAC 25.025) Travelers Indemnity Co. Type Blanket Surety and/or number 148F0140 Amount $200,000 _ 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 15. Distance to nearest drilling or completed 4 miles +-5880 feet well +1860 feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 18. Approximate spud date 12,000 MD & TVD feet 8785 November 1, 1981 19. If deviated (see 20 AAC 25.050) Nr/;~ 20. Anticipated pressures 4300 psig@ _ Surface KICK OFF POINT feet. M IMUM HoLE ANGLE o (see 20AAC25.035(c).(2) 5880 psig@12;00Oft. TD{TVD) 21 Proposed Casing, Liner and Cementing Program SIZE CASING AND LINER SETTING DEPTH QUANTITY OF CEMENT , Hole Casing Weight Grade Coupling Length MD TOP TVD MD BOTTOM TVD (include stage data) , - 20" Conduc tor +80, Surfac~ +-Ro, MD~. mVn Driven-no cement _ I ~7~t'' ~3 3/8 , 61 K-55 Butt 2700' Surface +-2700'gD,~VD See attachment 72~TM 9 5/8" 40.43.5N-80,S-95 LT&£10,O00 Surfac~ i±IO,OOOMD,TVD See attachment 8~t'' 7" 26 S-95 LT&C 12300' +-9700'MD.TV• !~12,00~MD,TVD See attachment I t ! 22. Describe proposed program: See attached Supplemental Data Sheets. Proposed location plat is enclosed. As-built survey will be submitted after setting conductor. Attached Surface Facilities Map shows the lease boundaries. BOP program: Surface to 2700' - 20", 2000 psi, SA diverter system. 2700' to 12,000' (TD) - 13 5/8", 5000 psi, SRRA assembly with 2", 5000 psi choke manifold. RECEIVED · 23.' hereby certify that~t to the best of my knowledge SEP 2 1 1981 SIGNED~ TITLE Pres i dentAJ~U~3 gl! ~ 0,.~ P,,nn~. ~8n~i$~ 5/81 The spacebelow for Cor~mission us~' R ' b'tewart Anchorage CONDITIONS OF APPROVAL. _ Samples required Mud log required Directional Survey required I APl number DYES J~NO DYES -~NO DYES I~NOJ 50- 283-20069 Permit number Approval date 81-145 09/29/81 j SEE COVER LETTER FOR OTHER REQUIREMENTS APPROVED BY ~ ,COMMISSIONER DATE September 29, 1981 by order of the Commission Form 10-401 Rev. 7-1-80 Submit in triplicate Supplemental Data Sheet Application for Permit to Drill SIMPCO Chuitna No. 1 September 15, 1981 I. Casing Program: 20" conductor pipe driven to +80' 13 3/8", 61 lb/ft, K-55, Buttress 9 5/8", 40 lb/ft, N-80, LT&C 9 5/8", 40 lb/ft, S-95, LT&C 9 5/8", 4'~.5 lb/ft, S-95, LT&C 7", 26 lb/ft, S-95, LT&C :Surface to +2700' :Surface to 4700' :4700' to 7100' :7100' to 10,000' :liner from 9700' to 12,000' The casing weights and grades listed above are preferred. At the time of purchase, however, it may be necessary to adjust slightly depending on availability. If adjustments are necessary, the performance properties of the final design Will meet or exceed the designs listed above. The Alaska Oil and Gas Conservation Commission office will be notified appropriately in the event a deviation from the above design is necessary. II. Cementing Program: A. The 13 3/8" surface casing will be cemented to surface with 1000 sacks of Class "G" containing 4% dry blend gel (includes 40% excess) followed by 950 sacks of Class "G" containing 2% calcium chloride (includes 30% excess). Duplex cementing technique will be used. B. The 9 5/8" intermediate casing string will be cemented with 700 sacks.of Class "G" cement containing fluid loss additives, turbulence inducer and retarder. This should yield a 2000' cement, column plus 30% excess. If potentially productive horizons are encountered above the projected cement top, a second stage cement job will be performed through a DV collar. C. The 7" liner will be cemented with 290 sacks of Class "G" cement containing fluid loss additives, turbulence inducer, and retarder. The liner hanger will be cement~ squeezed with 100 sacks of Class "G" containing the appropriate additives for cement squeezing. RECEIVED SEP 2 1 1981 Alaska Oil & Gas Cons. Commission Anchorage Supplemental Data Sheet Application for Permit to Drill SIMPCO Chuitna No. 1 September 15, 1981 I. Casing Program: 20" conductor pipe driven to +80' 13 3/8", 61 lb/ft, K-55, Buttress 9 5/8", 40 lb/ft, N-80, LT&C 9 5/8", 40 lb/ft, S-95, LT&C 9 5/8", 43.5 lb/ft, S-95, LT&C 7", 26 lb/ft, S-95, LT&C :Surface to +2700' :Surface to 4700' :4700' to 7100' :7100' to 10,000' :liner from 9700' to 12,000' The casing weights and grades listed above are preferred. At the time of purchase, however, it may be necessary to adjust slightly depending on availability. If adjustments are necessary, the performance properties of the final design will meet or exceed the designs listed above. The Alaska Oil and Gas Conservation Commission office will be ~notified appropriately in the event a deviation from the above design is necessary. II. Cementing Program: A. The 13 3/8" surface casing will be cemented to surface with 1000 sacks of Class "G" containing 4% dry blend gel (includes 40% excess) followed by 950 sacks of Class "G"' containing 2% calcium chloride (includes 30% excess). Duplex cementing technique will be used. T e " B. h .9~5~ intermediate casing string will be cemented with 700 sackS of Class "G" cement containing fluid loss additives, turbulence inducer and retarder. This should yield a 2000' cement column plus 30% excess. If potentially productive horizons are encountered above the projected cement top, a second stage cement job will be performed through a DV collar. C. The 7" liner will be cemented with 290 sacks of Class "G" cement containing fluid loss additives, turbulence inducer, and retarder. The liner hanger will be cement squeezed with 100 sacks of Class "G" containing the appropriate additives for cement squeezing. Each .cement job will be preceeded with a spacer fluid of the proper weight, viscosity, and inhibitors for formation stabilization. Actual cement volumes will be calculated from open hole electric log caliper data. III. Drilling Fluid Program: Surface to 2700 ' - Benex-gel/fresh water 2700' to 12,000 (TD) - Low solids polymer system IV. Anticipated Geology: Surface to 4960' - Beluga Formation 4960' t6 12,000' (TD) - Tyonek Formation V. Formation Evaluation: A. Standard mud logging equipment will be installed prior to spudding and will be used throughout drilling. B. One or more full size cores are anticipated to be cut at intervals to be determined by the wellsite geologist. C. Wireline logs run will include dual induction laterolog, compensated sonic log, compensated density- neutron log, and dipmeter. D. Horizons of indicated hydrocarbon potential will be tested by drillstem test procedures carefully minimizing formation damage. VI. Pressure Control Practices Drilling history in the immediate area has indicated that the pore pressure gradient at depth is about 0.49 psi/ft. Applying this to the projected total depth, the maximum anticipated bottom hole pressure is 5880 psi at 12,000' TVD. In the remote possibility that the hole were to become totally gas filled, the maximum surface pressure would reach 4300 psi using a gas gravity of 0.75 (air = 1.0), which has been measured from DST recoveries on other wells in the area. The "constant drill pipe pressure" method (Drillers Method) will be the well control method used on this well. This method results in the controlled expansion of the "kick" as it is circulated out of the wellbore minimizing potential surface pressures. RECEIVED SEP 1 1981 Alaska Oil & Gas Cons. Commission Anchorage Each cement job will be preceeded with a spacer fluid of the proper weight, viscosity, and inhibitors for formation · stabilization. Actual cement volumes will be calculated from open hole electric log caliper data. III. Drilling Fluid Program: Surface to 2700 ' - Benex-gel/fresh water 2700' to 12,000 (TD) - Low solids polymer system IV. Anticipated Geology: Surface to 4960' - Beluga Formation 49~60' t6 12,000' (TD) - Tyonek Formation V. Formation Evaluation: A. Standard mud logging equipment will be installed prior to spudding and will be used throughout drilling, B. One or more full size cores are anticipated to be cut at intervals to be determined by the wellsite geologist. C. Wireline logs run will include dual induction laterolog, compensated sonic .log, compensated density- neutron log, and dipmeter. D. Horizons of indicated hydrocarbon potential will be tested by drillstem test procedures carefully minimizing formation damage. VI. Pressure Control Practices Drilling history in the immediate area has indicated that the pore pressure gradient at depth is about 0.49 psi/ft. Applying this to the projected total depth, the maximum anticipated bottom hole pressure is 5880 psi at 12,000' TVD. In the remote possibility that the hole were to become totally gas filled, the maximum surface pressure would reach 3~i using a gas gravity of 0.75 (air = 1.0), which has been measured from DST recoveries on other wells in the area. The "constant drill pipe pressure" method (Drillers Method) will be the well control method used on this well. This method results in the controlled expansion of the "kick" as it is circulated out of the wellbore minimizing potential surface pressures. SEP 2 I, 1981 A~sKa Oil & Gas Cons. Comrnis~]g AnchoragQ~ Active Fluid Level Fill-u~._~ Line Flow Line 20" Hydril MSP diverter 2000 p s i Kill gage Line_~ ~ Cella~ / ? / 20" drilli spool /./ PROFILE VIEW 17 "_SURFACE HOLE BOPE DIVERTER ARRANGEMENT All turns to be long-radius Minimum of 4' of freeboard above active fluid level. 6" (min.) line pipe air or steam for purging To diverter manifold Inverted "U" Tube Diverter System~ If a kick is experienced, closing the ~.~ Hydril diverter will immediately allow~ the wellbore fluid to flow through the inverted "U" tube to the diverter mani- fold which always has one valve open. Operation of the quick 6pening butterfly valves in the diverter manifold, to control the direction of flow, is accomp- lished manually. To end of rese~-e pit 1. System is always open to flow (no closed valve) and is therefOre fail-safe. 2. System does not require automating valves with the BOP controls. To end of reserve pit DIVERTER MANIFOLD 17 112' 8URFACE HOLE BOPE DIYE~RTE R ARRANGEMENT · I~ 3. System is simple and I I trouble free. 4. Outlet from the drilling Mech. spool is sloped toward linkag ~ . the spool for self- L~ ~,~o open~ cleaning. (~_-- ~ ~lOuick_open 5. Entire system downstream ~_~lbutterfly of "U" tube is sloped I~ ][ ~valves toward reserve pit for ~ I ~~ drainage. o clOse 6. System can be purged with !l~/~-~/z°'~~ air or steam. J ~' SIMPCO CHUITNA NO. I Active Fluid Level Line Flow Line 20" Hydril MSP diverter 2000 p s i Kill Line._~ gat " 20" drilli: spool ') ,, · r / / // /' /' Cella~ / ? / PROF1LE VIEW !7~"_SURFACE HOLE BOPE D IVERTER..ARRANGEMENT All turns to be long-radius Minimum of 4' of freeboard above active I fluid level. 6" (min.) pipe air or steam for purging To diverter manifold I, Mech. Inverted "U'" Tube Diverter System If a kick is experienced, closing the Hydril diverter will immediately allow the wellbore fluid to flow through the inverted "U" tube to the diverter mani- fold which always has one valve open. Operation of th~ quick ~%ning butterfly valves in the diverter manifold, to control the direction of flow, is accomp- lished manually. To end of reselvepit 1. System is always open to flow (no closed valve) and is therefore fail-safe. 2. System does not require automating valves with the BOP controls. 3. System is simple and trouble free. 4. Outlet from the drilling spool is sloped toward the spool for self- .to open ~ cleaning. Quick-open 5. Entire system downstream butterfly of "U" tube is sloped valves toward reserve pit for ~_/ drainage. o close 6. System can be purged with _.- ,, air or steam. d,~ ; ~.~.- /~'z~7 "~-'. ~-. -/-~~ SIMPCO CHUITNA NO. I 17 112° SURFACE HOLE - BOPE. DIYE~RTER .ARRANGEMENT To end of reserve pit D I VERI'ER MAN I FOLD I I I 25 30 I I ~ I I I I I I I I ~ I I 36 I 31 I 32 3~ I 34 , I C~ I I ..J SCALE= I"= IMILE ! I 1 ~ T. 12 N. -d IT. lIN. I I CERTIFICATE OF SURVEYOR ' I hereby certify that I am properly registered and licensed to practice land surveying in the State of Alaska and that this plat represents a location survey made by me or under my supervision, and that a. II dimensions and other details are correct. RECEIVE S£P 2 ]. ]98i ' Da t e SURVgYOR An~h~;~'g'~ Comrnissiorl (PROPOSED) SIMPCO CHUlTNA No.I Located in SW I/4 PROTRACTED SEC Surveyed for SIMASKO PRODUCTION CO. Surveyed by F.M. LINDSEY I~ ASSOC. LAND & HYDROGRAPHIC SURVEYORS 2502West Northern Lighte Boulevard Box 4-081 Anchoroge, Alaska A- ~2535 C~SIHG STRTNG CASINO SI~ =~77 sIZE FIELD COUh~Y STATE · HYD OR. i DAgE bP JO %5. II DESIGN BY psi/f=. 'M.S.P. . Ih'2ERVAL iZ:,[5 ~?: DESCPgP~Oi.~r Bottom Top Wt. Grade T-r.r cad w/ BP .. W/O BP lbs TENSION -top of section 'los T£NSiON !030 lbs TDF COLL~3SE PAESS. @ bottcrm COLL~SE CDP BDF PP_rCE PER ~T_. Cf 7 7/~° JT~ o LZ~oo ¢,.,7`,0 - _ ?ormulae: Co!lapsc resistance in tension = (Collapse press~hre ratify) ~arst Pressure = ~? · Depth ( }{yd. Gr. II --.5) BF (Bouyancy Factor) = 1.oo- (o.0153 x i,:ua wt. z) Calculations: I. To-~l Ccst ,.© I ! ANNULAR PREVENTER I~'/,, 5000 5~," I "J [ ,~%':~ooo ! [ DOUBLE GATE RAMS (BUND) ~tm' fo ...... Rotow I ~ ! ..... ..~. ~ ...., ~.~ ~. ~6~" ,! , . · ~ ....... ~ - S~L ~SIN; t~' ~'/," II II Ic~s'"° " { ~ I'a~ ~llar fl~ I , 5000 psi SRRA BOP ARRANGEMENT (WHILE 'DRILLING 12l/4 '~ HOLE) 5000 psi SRRA BOP ARRANGEMENT (WHILE DRILLING 8~"HOLE) ANNULAR / PREVETER i3%': 5ooop~ I r~k," 5000 DOUBLE 6ATE RAMS (BUND) ! ~%': 5000 ! '1 1~ ,3%'; 5000 Est. 18' to RB°:i rrnY~ ~I DRILL. lNG 1~ , :~,, i.oo L°L~r' .{ ' ! ,o: ~ooo .... I .o: ooo '~ t~" I ~ ~BING '~' .t. 29" ~ CASING SPOOL ~o: ~ooo *~ ~1 I CASING :t..,][ above c~ller fk~Weld g20" CASING CHOKE MANIFOLD.SCHEMATIC 5000PSI WORKING PRI"'SSURE HCR ValVe (t) $"x2" / 5000 psi crossesN.~ Premure ~ ~. 2" Ells or Long Radius 90° Ells Remote Operated Hydraulic Choke .Hand Hand Ad Adjust I. All valves' to be full- opening. ~ 2. All volves to be 5000psi rated. Oegasser R :~ Ail manifoM components 'to be Mud Tanks ring-joint flanged. To Oegasser And Mud Tonks i Simasko Production Company ANCHORAGE' OENV&R ! ~IMP~O CHUlTNA NO~ 80P; FOR 1~ , SCALE DR. AM8 DATE 8EP.teBt CK'O.. BA SEP 2 [ 198! -. Gas Cons. Gommissi_o',Tt CHECK LiST FOR NEW WELL PERMITS Company Lease & Well No. ITEM APPROVE DATE Loc ~ '~'~ t 8) (3) Admin(~~thru11)~'L'6~$) (4) Is the permit fee attached ........................................ 2. Is well to be loCated in a defined pool ................... ........ 3. Is well located proper distance from property line ...... 4. Is well located proper distance from other wells ...ii.~. 5. Is suff{cient undedicated acreage available in this po°l . 6. Is well to be deviated and is well bore plat included ............. 7. Is operator the only affected party ............................... 8. 0 10. 11. Casg[~,~ ' ~-~Z~/ 12. Zd12 £hru 50) 13 14. 15. 16. 17. 18. 19. 20. (5) BOPE ~~- ~;--~,3 ~,a~,/ 21. --/----(/21 thru 24) 22. 23. 24. (6) Add :.~~ / YES NO _ b d b f dy i ' Can permit e approve e ore ten- a wa t .......................... __ ..... Does Operator have a bond in force ......... .... .~... Is a conservation order needed .... . ..... Is administrative approval needed .[ ! '{{' !{'ii![!i!!'{{i ili''[i " Is conductor string Provided ....... ............. ........ ' .......... Is enough cement used to circulate on conductor and surface'"'. Will cement tie in surface and intermediate or production strin Sg Will cement cover all knoim productive horizons .................. Will surface casing protect fresh water zones ...... ' ....... i. . Will all casing give adequate safety in collapse, tension and burst Is this well to be kicked off from an existing wellbore .... ....... Is old wellbore abandonment procedure included on 10-403 ...... .... Is adequate well .bore separation proposed ......................... Does BOPE have sufficient pressure' rating- Test to~ 'P. Does the choke manifold comply w/AP1 RP-53 (Feb.7s).'17772]~ .... Additional requirements Additional Remarks:_ REMARKS Geology: HWK~ JAL~ Engine ~r~in~g~: rev" 03/10/81 ........ iNiTIAL I GEO. UNIT 'ON/OFF! PooL CLASS STATUS AREA NO. SHORE