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Home My WebLink About2018-05-23_318-217STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25 280 MAY 2 3 2018 Fr 90 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑✓ Repair Well p ❑ Operations shutdown El Suspend ❑ Perforate ❑✓ Other Stimulate ❑ Pull Tubin g ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: CT FCO w/ N2 ❑✓ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Hilcorp Alaska LLC Exploratory ❑ Development ❑✓ Stratigrephic El Service Q 217-077 3. Address: 3800 Centerpoint Dr, Suite 14006. API Number: Anchorage Alaska 99503 50-029-23577-00-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? C.O. 432D Will planned perforations require a spacing exception? Yes ❑ No ❑✓ MPU C-47 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL047434 / ADL047433 Milne Point/ Kuparuk River Oil 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (tt): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 10,293' 7,162' 6,385' 6,385' 2,974 6,385' N/A Casing Length Size MD TVD Burst Collapse Conductor 151' 16" 151' 151' N/A N/A Surface 6,564' 9-5/8" 6,590' 4,886' 5,750psi 3,090psi Intermediate 142' 7" 165' 165' 7,240psi 5,410psi Intermediate 2495- 7" 9,510' 6,882' 7,240psi 5,410psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Schematic See Schematic 3-1/2" 9.3 / L-801 EUE 8rd 3,007' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): N/A and N/A N/A and N/A 12. Attachments: Proposal Summary ✓ Wellbore schematic Ej 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Strati ra hic g p ❑ Development ❑✓ Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 6/5/2018 OIL Q WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: So York Contact Name: Paul Chan Authorized Title: Operations Manager Contact Email: Chan hilcor .00111 Contact Phone: 777-8333 Authorized Signature: Date: —J -1r --j lit 4 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3 t -7 Plug Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes ❑ No ❑ Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THECOMMISSION Date: Submit Form and Forth 10403 Revised 412017 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate Hilcorp Alaska, LLC May 22, 2018 Post Office Box 244027 Anchorage, AK 99524-4027 3800 Centerpoint Drive Suite 1400 Anchorage, AK 99503 Paul Chan Senior Operations Engineer (907)777-8333 MAY 2 3 2018 Hollis S. French, Chair Alaska Oil and Gas Conservation Commission AOGCC 333 West 7`n Avenue, Suite 100 Anchorage, Alaska 99501 RE: Hydraulic Fracturing Application, Milne Point Unit, MP C-47 Dear Commissioner French, Hilcorp Alaska, LLC ("Hilcorp'), as Operator of the Milne Point Unit, herein submits its application to fracture stimulate MP C-47. Please do not hesitate to contact Paul Chan at 907-777-8333 should you have any questions regarding this application. Sincerely, BOY Operations Manager HILCORP ALASKA, LLC Enclosures: Form 10-403 Sundry Attachments Redacted For Public Disclosure 20 AAC 25.283 (a)(1) Affidavit Affidavit stating that all owners, landowners, surface owners, and operators within a one-half mile radius of the current or proposed wellbore trajectory have been provided a notice of operations that is in compliance with 20 AAC 25.283 (a)(1) VERIFICATION OF NOTICE PER 20 AAC 25.283(a) MILNE POINT UNIT MP C-47 I, PAUL CHAN, Hilcorp Alaska, LLC, ("Hilcorp") do hereby verify the following: I am acquainted with Hilcorp Alaska, LLC's application for sundry approval to the Alaska Oil and Gas Conservation Commission to enhance production of the MP C-47 well via hydraulic fracturing. Pursuant to 20 AAC 25.283(a)(1), I assert that all owners, landowners, surface owners, and operators within a one-half mile radius of the current or proposed wellbore trajectory have been provided notice of Hilcorp Alaska, LLC's proposed operations. DATED at Anchorage, Alaska this�2 day of Pa Chan, Sr. perations Engineer Hilcorp Alaska, LLC STATE OF ALAKSA THIRD JUDICIAL DISTRICT SUBSCRIBED TO AND SWORN before me this 2 day of _KD -Q 2018 NOI PUBgq IN AND FOR THE STATE F LSKA My Commission expires: eco Zo2 STATE OF ALASKA NOTARY PUBLIC "ry Cortney M. Moore My Commisslon Expires: April 28, 2021 20 AAC 25.283 (a)(2) A Plat Redacted For Public Disclosure (A) Showing The Well Location; (B) Identifying each Water Well, if any, Located within a One -Half Mile Radius of the Well's Surface Location; and Sec. 4 Sec. 3 Sec. 2 MPU C-47_BHL Frac Zone ADL047434 ADL047433 .,.'.,.1......... �,�. ♦'�,♦ S/11 Sec. 9 �,�`� Sec. 10 i i i i • U013NO10E ! MPU MPU C-47_SHL .�C ■ i i ♦, i Sec. 16 ADL315848 ADL025516 Legend • Top of Frac Zone o Base of Frac Zone • Surface Hole Location (SHL) MPC-47 Well Trajectory MPC-47 (wp13) as ■��,� 1/2 Mile Radius from SHL Pad Footprint Petra Well Database - HAK Milne Point Unit MPC wp13 Dr JlC 11iienterp MPC-47 Well No Waatt er Wells Within 1/2 Mile iv aeon ceme�pom�on Suite iaoo ut 0 500 1,000 1,500 `" h.ra,e A"'99503 Plat depicting no water wells with 1/2 mile of the MP C-47 SHL °Feet Map Date'. 522/2018 Redacted For Public Disclosure (C) Identifying for all Well Types each Well Penetration Well API PTD Pool Type Status MPC -01 50029206630000 1811430 KR ESP Producing MPC -02 50029208660000 1821940 KR WAG Injecting MPC -03 50029207860000 1820500 KR 1 -OIL Producing MPC -04 50029208010000 1821260 KR 1 -OIL Producing MPC -05A 50029212440100 1842430 KR 1 -OIL Shut In MPC -06 50029212570000 1842410 KR WAG Injecting MPC -07 50029212660000 1850020 KR 1 -OIL Producing MPC -08 50029212770000 1850140 KR WAG Shut In MPC -09 50029212990000 1850360 KR 1 -OIL Producing MPC -30 50029212780000 1850150 KR WAG Injecting MPC -11 50029213210000 1850590 KR PWI LTSI MPC -12A 50029213730100 1990910 KR SUSP Suspended MPC -13 50029213280000 1850670 KR ESP Producing MPC -14 50029213440000 1850880 KR ESP Producing MPC -15A 50029213580100 2160700 SR JET Producing MPC -16 50029213640000 1851100 KR SUSP Suspended MPC -17 50029214730000 1852630 KR WAG Shutln MPC -18 50029214790000 1852690 P&A P&A MPC -19 50029215040000 1852960 KR WAG Shut In MPC -20 50029219140000 1890150 KR 1 -OIL LTSI MPC -21 50029224860000 1940800 KR 1 -OIL Shut In MPC -22A 50029224890100 1951980 KR ESP Producing MPC -23 50029226430000 1960160 SR JET Producing MPC -24A 50029230200100 2091340 KR 1 -OIL Producing MPC -25A 50029226380100 1960210 KR WAG Shut In MPC -26 50029226340000 1952060 KR JET Producing MPC -28A 50029226480100 2051630 KR WAG Injecting MPC -36 50029228530000 1980010 KR WAG Injecting MPC -39 50029228490000 1972480 KR WAG Injecting MPC -40 50029228710000 2002130 KR JET Producing MPC -41 50029230140000 2010780 SB PWI Injecting MPC -42 50029231960000 2040280 KR WAG Injecting MPC -43 50029232000000 2040390 KR ESP Producing MPC -45 50029232000000 2170920 KR GL Producing MPC -46 50029235760000 2170520 SR 1-011. Shut In Redacted For Public Disclosure Redacted For Public Disclosure 20 AAC 25.283 (a)(3) Identification of Freshwater Aquifers There are no underground sources of drinking water within a one-half mile radius of the current wellbore trajectory. Any and all freshwater aquifers lying below the Milne Point Unit are exempted aquifers under Aquifer Exemption Order 2 (AEO-2). See the Conclusion of AEO-2, which states that "The portions of freshwater aquifers lying directly below Milne Point Unit qualify as exempt freshwater aquifers under 20 AAC 25.440." Redacted For Public Disclosure 20 AAC 25.283 (a)(4) Baseline Water Well Sampling There are no water wells located within one-half mile radius of the current wellbore trajectory. Redacted For Public Disclosure 20 AAC 25.283 (a)(5) Detailed Casing and Cementing Information 9-5/8" 40#/ft L-80 DWC/C surface casing set at 6,590' MD with stage tool at 2,007' MD. First stage cemented with 700 sxs / 308 bbls of 11.7 ppg cement followed by 295 sxs / 60.7 bbls of 15.8 ppg SWIFT Cern cement. Second stage cemented with 335 sxs / 259 bbls of 10.7 ppg PermaFrost L followed by 175 sxs / 36.2 bbls of 15.8 ppg Class G cement. Proposed: 7" 26#/ft L-80 TXP-SR production casing set at —10,688' MD. Cement with 471 ft'/407 sxs of 15.8 ppg SwiftCEM cement. Detailed Casing Information Size Type Wt/ Grade/ Conn Pipe Body Yield (Ibs) Collapse Pressure (psi) Internal Yield Pressure (psi) Conductor N/A N/A N/A N/A 9-5/8" Surface 40# / L-80 / DWC/C 916,000 3,090 5,750 7" Production 26# / L-80 / TXP-SR 604,000 5,410 7,240 Detailed Tubing Information 4-Y" Tubing 12.6 / L-80 / TXP-SR 288,000 7,500 8,430 Redacted For Public Disclosure 20 AAC 25.283 (a)(6) Assessment of Each Casing and Cementing Operation Performed to Construct or Repair the Well The 9-5/8" surface casing was set below the base of the Schrader Bluff sands. The first stage cement job was started by pumping 60 bbls of 10.5 ppg tuned spacer with red dye followed by 700 sxs / 308 bbls of 11.7 ppg ExtendaCem lead cement and 295 sxs / 60.7 bbls of 15.8 ppg SwiftCem tail cement at 4 BPM average rate. 62 bbls was lost during the first stage cement job. The stage tool was then opened and the tuned spacer and 67 bbls of green cement were circulated out. The second stage was cemented by first pumping 60 bbls of 10.5 ppg tuned spacer followed by 335 sxs / 259 bbls of 10.7 ppg PermaFrost L lead cement and 175 sxs / 36.2 bbls of 15.8 ppg Class G cement tail at 4 BPM average rate. Recovered 185 bbls of cement at surface. Bumped plug and closed stage tool at 1200 psi. Floats held. 9 bbls were lost during the second stage cement job. The job was pumped with cement to surface indicating a competent cement job. Redacted For Public Disclosure 20 AAC 25.283 (a)(7) Plans to Pressure -Test the Casings and Tubing Installed in the Well The 9-5/8" casing was pressure tested to 3000 psi for 30 minutes on July 23, 2017. The 7" casing will be pressure tested to 3000 psi for 30 minutes. Post rig the 4-%" tubing will be pressure tested to 4500 psi for 30 minutes. The 4-1/2" x 7" annulus will be pressure tested to 3000 psi for 30 minutes. Redacted For Public Disclosure 20 AAC 25.283 (a)(8) Pressure Ratings and Schematics for the Wellbore, Wellhead, BOPS, and Treating Head Size Weight #A Grade API Collapse Pressure (psi) API Internal Yield Pressure (psi) 9-5/8" 40 L-80 3,090 5,750 7" 26 L-80 5,410 7,240 Treating Head 15M Wellhead 5M BOPE N/A Redacted For Public Disclosure 20 AAC 25.283 (a)(9) Data for the Fracturing Zone and Confining Zones (A) a lithologic description of each zone; (B) the geological name of each zone; (C) the measured depth and true vertical depth of each zone; (D) the measured thickness and true vertical thickness of each zone; and (E) the estimated fracture pressure for each zone; Redacted For Public Disclosure 20 AAC 25.283 (a)(10) The Location, the Orientation, and a Report on the Mechanical Condition of Each Well that May Transect the Confining Zones Redacted For Public Disclosure 20 AAC 25.283 (a)(11) The Location of, Orientation of, and Geological Data for Each Known or Suspected Fault or Fracture that May Transect the Confining Zones Redacted For Public Disclosure 20 AAC 25.283 (a)(12) Proposed Hydraulic Fracturing Program Redacted For Public Disclosure 20 AAC 25.283 (a)(12) (A) Estimated Total Volumes Planned 20 AAC 25.283 (a)(12) (B) Trade Name, Generic Name, and Purpose of each Base Fluid and Additive to be Used; 20 AAC 25.283 (a)(12) (C) Chemical Ingredient Name of, and the Chemical Abstracts Service (CAS) Registry Number Assigned to, each Base Fluid and Additive to be used; 20 AAC 25.283 (a)(12) (D) Estimated Weight or Volume of each Inert Substance, including a Proppant or other Substance injected Redacted For Public Disclosure 20 AAC 25.283 (a)(12) (E) Maximum Anticipated Treating Pressure and Information Sufficient to Support a Determination that the Well is Appropriately Constructed for the Proposed Hydraulic Fracturing Program. The 4-%: "production tubing will be tested to 4500 psi for 30 minutes and the 7" production casing will be tested to 3000 psi for 30 minutes prior to the fracture stimulation. The maximum differential pressure the tubing will be subjected to will be 4300 psi (6800 psi GORV maximum pressure setting - 2500 psi of pressure on the casing x tubing annulus). The calculated maximum treating pressure is 4,876 psi. Redacted For Public Disclosure 20 AAC 25.283 (a)(12) (F) Designed Height And Length Of Each Proposed Fracture (i) the calculated measured depth and true vertical depth of the top of the fracture: (ii) a description of each method and assumption used to determine designed fracture height and length: Redacted For Public Disclosure 20 AAC 25.283 (a)(13) Description of the Plan for Post -Fracture Wellbore Cleanup and Fluid Recovery through to Production Operations The well will be cleaned up through a portable separation system before turning the well over to Production. Initial returns will be taken to the permitted Milne Point G&I facility for disposal.