Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation Commission
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David Dempsey Hilcorp Alaska, LLC
Sr. Geotechnician 3800 Centerpoint Drive, Suite 1400
Anchorage, AK 99503
Tele: (907) 777-8337
E-mail: david.dempsey2@hilcorp.com
Please acknowledge receipt by signing and returning one copy of this transmittal.
Received By: Date:
Date: 10/3/2022
To: Alaska Oil & Gas Conservation Commission
Natural Resource Technician
333 W 7th Ave Suite 100
Anchorage, AK 99501
SFTP DATA TRANSMITTAL T#20220930
Well API #PTD #Log Date Log
Company Log Type AOGCC Eset#
MPU I-17 500292321200 204098 3-Aug-22 READ CaliperSurvey
MPU B-24 500292264200 196009 7/19/2022 READ CaliperSurvey
MPU F-38 500292261400 195168 9/19/2022 READ CaliperSurvey
MPU F-73A 500292274401 200198 7/31/2022 READ CaliperSurvey
MPU I-01 500292206500 190090 8/31/2022 READ CaliperSurvey
MPU I-30 500292371000 222023 7/12/2022 READ Inj_Profile
MPU J-27 500292355700 215153 8/11/2022 READ CaliperSurvey
MPU L-47 500292355000 215117 7/23/2022 READ CaliperSurvey
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T37121
T37122
T37123
T37124
T37125
T37126
T37127
T37128
MPU I-30 500292371000 222023 7/12/2022 READ Inj_Profile
Kayla
Junke
Digitally signed
by Kayla Junke
Date: 2022.10.05
13:20:28 -08'00'
Kaitlyn Barcelona Hilcorp Alaska, LLC
GeoTechnician 3800 Centerpoint Drive, Suite 1400
Anchorage, AK 99503
Tele: 907 564-4389
E-mail: kaitlyn.barcelona@hilcorp.com
Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 564-4422
Received By: Date:
Date: 07/19/2022
To: Alaska Oil & Gas Conservation Commission
Natural Resource Technician
333 W 7th Ave Suite 100
Anchorage, AK 99501
SFTP DATA TRANSMITTAL
Well API # PTD # Log Date Log Company Log Type Notes AOGCC Eset #
MPU I-30 50029237100000 222023 07/12/2022 Read IPROF
Please include current contact information if different from above.
T36816
Kayla Junke
Digitally signed by Kayla
Junke
Date: 2022.07.21 12:44:50
-08'00'
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KďũĞĐƚŝǀĞ͗
ϭͿ ZƵŶ/WZK&ƚŽĚĞƚĞƌŵŝŶĞ ǁŚĞƌĞƚŚĞD ŚĂƐĨŽƌŵĞĚ͘
ϮͿ WƵŵƉ ĞŵĞŶƚͬ'Ğů ŽŶĨŽƌŵĂŶĐĞdƌĞĂƚŵĞŶƚƚŽƌĞŵĞĚŝĂƚĞD ďĞƚǁĞĞŶ /ͲϯϬŝ ĂŶĚ /ͲϮϵ͘
ZŝƐŬƐ
x džĐĞĞĚŝŶŐĨƌĂĐƚƵƌĞƉƌĞƐƐƵƌĞ͘
o ƐƐƵŵŝŶŐĂϬ͘ϲϲƉƐŝͬĨƚĨƌĂĐƚƵƌĞŐƌĂĚŝĞŶƚ͕ƚƌLJƚŽƌĞĚƵĐĞƐƵƌĨĂĐĞƉƌĞƐƐƵƌĞĂƐŵƵĐŚĂƐ ƉŽƐƐŝďůĞ͘
x WƌŽĚƵĐƚŝŽŶŝŶƉƌŽĚƵĐĞƌ
o WƌŽĚƵĐĞƌ /ͲϮϵ ƐŚŽƵůĚďĞƐŚƵƚͲŝŶ ĚƵƌŝŶŐƚƌĞĂƚŵĞŶƚŽĨƚŚĞũŽď͘
WƌŽĐĞĚƵƌĞ͗
dh͗
EŽƚĞƐ͗
ƵĞƚŽƚŚĞŶĞĐĞƐƐĂƌLJŽƉĞŶŚŽůĞĚĞƉůŽLJŵĞŶƚŽĨ džƚĞŶĚĞĚ,͕ϮϰͲŚŽƵƌĐƌĞǁĂŶĚt^^ĐŽǀĞƌĂŐĞŝƐƌĞƋƵŝƌĞĚ͘
dŚĞǁĞůůǁŝůůďĞŬŝůůĞĚĂŶĚŵŽŶŝƚŽƌĞĚďĞĨŽƌĞŵĂŬŝŶŐƵƉƚŚĞĞdžƚĞŶĚĞĚ,͘dŚŝƐŝƐŐĞŶĞƌĂůůLJĚŽŶĞĚƵƌŝŶŐƚŚĞ
ĚƌŝĨƚͬůŽŐŐŝŶŐƌƵŶ͘ dŚŝƐǁŝůůƉƌŽǀŝĚĞŐƵŝĚĂŶĐĞĂƐƚŽǁŚĞƚŚĞƌƚŚĞǁĞůůǁŝůůďĞŬŝůůĞĚďLJďƵůůŚĞĂĚŝŶŐŽƌĐŝƌĐƵůĂƚŝŶŐ
ďŽƚƚŽŵƐƵƉƚŚƌŽƵŐŚŽƵƚƚŚĞũŽď͘
ϭ͘ D/ZhŽŝůĞĚdƵďŝŶŐhŶŝƚĂŶĚƐƉŽƚĂƵdžŝůŝĂƌLJĞƋƵŝƉŵĞŶƚ͘
Ϯ͘ WƌĞƐƐƵƌĞƚĞƐƚKW ƚŽ ϯ͕ϱϬϬƉƐŝ,ŝϮϱϬ>Žǁ͕ϭϬŵŝŶ,ŝŐŚ͕ϱŵŝŶ>ŽǁĞĂĐŚƚĞƐƚ͘
Ă͘ /ĨKW ƚĞƐƚŚĂƐŶŽƚďĞĞŶĐŽŵƉůĞƚĞĚŝŶůĂƐƚϳĚĂLJƐ͕ƚĞƐƚKW ƚŽϮϱϬƉƐŝŐůŽǁͬϮ͕ϱϬϬƉƐŝŐ
ŚŝŐŚ͘
ď͘ EŽK'ŶŽƚŝĨŝĐĂƚŝŽŶƌĞƋƵŝƌĞĚ͘
Đ͘ ZĞĐŽƌĚKW ƚĞƐƚƌĞƐƵůƚƐŽŶϭϬͲϰϮϰĨŽƌŵ͘
SSJJUDGLHQW
/WZK&ͬD dƌĞĂƚŵĞŶƚ
tĞůů͗ DW/ͲϯϬ
ĂƚĞ͗ ϲͬϮϳͬϮϮ
Ě͘ /ĨǁŝƚŚŝŶƚŚĞƐƚĂŶĚĂƌĚϳͲĚĂLJƚĞƐƚKW ƚĞƐƚƉĞƌŝŽĚĨŽƌDŝůŶĞWŽŝŶƚ͕ĂĨƵůůďŽĚLJƚĞƐƚĂŶĚ
ĨƵŶĐƚŝŽŶƚĞƐƚŽĨƚŚĞƌĂŵƐŝƐƐƵĨĨŝĐŝĞŶƚƚŽŵĞĞƚǁĞĞŬůLJKW ƚĞƐƚƌĞƋƵŝƌĞŵĞŶƚ͘
Ğ͘ ĂĐŚƐƵďƐĞƋƵĞŶƚƚĞƐƚŽĨƚŚĞůƵďƌŝĐĂƚŽƌǁŝůů ďĞƚŽ ϯ͕ϱϬϬƉƐŝ,ŝϮϱϬ>ŽǁƚŽĐŽŶĨŝƌŵŶŽůĞĂŬƐ͘
ϯ͘ ŶƐƵƌĞWƌŽĚƵĐĞƌ /ͲϮϵ ŚĂƐďĞĞŶŽŶůŝŶĞĨŽƌϰϴŚŽƵƌƐĂŶĚŝƐƌĞĂĚLJƚŽďĞƐŚƵƚŝŶĂƐ 'ĞůͬĞŵĞŶƚ ĞŶƚĞƌƐ
ƚŚĞĨŽƌŵĂƚŝŽŶ͘
ϰ͘ ƐƚĂďůŝƐŚƐŝƚĞĐŽŶƚƌŽůĂŶĚĂƐĞƉĂƌĂƚĞƌĂĚŝŽĐŚĂŶŶĞůĨŽƌĐƌĞǁƐƐŽƚŚĂƚĂƉƌŽƉĞƌĂŶĚĐůĞĂƌ
ĐŽŵŵƵŶŝĐĂƚŝŽŶĐĂŶĞdžŝƐƚƚŚƌŽƵŐŚƚŚĞũŽď͘
ϱ͘ Dh:^EǁŝƚŚKŽĨƚŚĞ/WZK&,ĚƌŝĨƚƚŽd͘/ĨƐĂĨĞͲůƵďĞŝƐŶĞĞĚĞĚƚŽƌĞĂĐŚdůŽĂĚǁĞůůǁŝƚŚƐĂĨĞ
ůƵďĞĂƐǁĞWKK,ƚŽĞŶƐƵƌĞ/WZK&ƌĞĂĐŚĞƐd͘ &ůĂŐƉŝƉĞ ĞǀĞƌLJϮϬϬϬ ƚŽĂǀŽŝĚ ƚĂŐŐŝŶŐ dǁŝƚŚ/WZK&
, ĂŶĚĨŽƌƉĂĐŬĞƌƉůĂĐĞŵĞŶƚ͘
ϲ͘ Dhd͕s͕ĐĂƌƌŝĞƌĂŶĚŵĞŵŽƌLJƐƉŝŶŶĞƌ;ŝŶͲůŝŶĞͬĨƵůůďŽƌĞͬƉƌĞƐƐͬƚĞŵƉͿ/WZK&,͘
ϳ͘ tŝƚŚƚŚĞǁĞůůƐƚĂƚŝĐĚŽŶŽƚƉƵŵƉĚŽǁŶĐŽŝůĚƵƌŝŶŐƚŚĞďĂƐĞůŝŶ ĞŽƌůŽŐŐŝŶŐƉĂƐƐĞƐ͘
ϴ͘ Z/,ƚŽĚĞǀŝĂƚŝŽŶ͘WĞƌĨŽƌŵƐƉŝŶŶĞƌĐĂůŝďƌĂƚŝŽŶǁŝƚŚǁĞůů^/ǁŚŝůĞZ/,͘
ϵ͘ /ĨůŽĐŬƵƉǁĂƐ ƌĞĂĐŚĞĚǁŝƚŚŽƵƚƐĂĨĞͲůƵďĞĂŶĚǁĞůůƌĞƋƵŝƌĞƐŵŽƌĞƐĂĨĞͲůƵďĞƚŽƌĞĂĐŚdƉƵŵƉƐĂĨĞ
ůƵďĞĚŽǁŶƚŚĞďĂĐŬƐŝĚĞĂŶĚŶŽƚĚŽǁŶd͘dŚŝƐŝƐƚŽƌĞĐŽƌĚĂŶLJƐƉŝŶŶĞƌƌĞƐƉŽŶƐĞƚŚĂƚŵĂLJƐŚŽǁ
ǁŚĞƌĞƚŚĞD ŝƐƉƌĞƐĞŶƚ͘
ϭϬ͘ Z/,ƚŽ d͘
ϭϭ͘ ƌŝŶŐ/ͲϯϬŽŶŝŶũĞĐƚŝŽŶĂƚ ϮϱϬϬtWƌĂƚĞ͘E ϳϱϬƉƐŝt,/W͘
ϭϮ͘ ĨƚĞƌ ϮϬϬďďůƐŽĨŝŶũĞĐƚŝŽŶƉĞƌĨŽƌŵ ŝŶũĞĐƚŝŽŶ ƉĂƐƐ͕ůŽŐŐŝŶŐƵƉĂƚ цϭϮϬ&WDƚŽ ϱ͕ϵϯϯ D͘
ϭϯ͘ >ŽŐƌĞƉĞĂƚƉĂƐƐ ĚŽǁŶĂŶĚďĂĐŬƵƉƚŽdͬ>ŽĐŬƵƉ ĂƚϵϬ&WD
ϭϰ͘ WKK,ĂŶĚĚŽǁŶůŽĂĚĚĂƚĂƚŽĐŽŶĨŝƌŵŐŽŽĚĚĂƚĂ͘^ĞŶĚ ĚĂƚĂƚŽŚ ƌŝƐ'ƵůůĞƚĂŶĚ&ĂŶŶLJ,ĂƌŽƵŶĨŽƌ
ĂŶĂůLJƐŝƐ͘
Ă͘ EŽƚĞ͗ŝƐƉůĂLJ>ƚƌĂĐŬĨƌŽŵĨŝŶĂůhƉƉĂƐƐͬ&ůĂŐŐŝŶŐZƵŶĂƐŵĂŝŶ>ĚŝƐƉůĂLJƚŽďĞƵƐĞĚ
ĨŽƌĐŽƌƌĞůĂƚŝŽŶ͘
ď͘ ^ĞŶĚƚŽK ƌŝĂŶ'ůĂƐŚĞĞŶƚŽĚŝƐĐƵƐƐƉĂĐŬĞƌƉůĂĐĞŵĞŶƚƐĨŽƌD ƚƌĞĂƚŵĞŶƚ͘
ϭϱ͘ ƚƐƵƌĨĂĐĞ͕ƉƌĞƉĂƌĞ ĨŽƌĚĞƉůŽLJŵĞŶƚŽĨ ƚƌĞĂƚŵĞŶƚ,ǁŝƚŚd͕d͕ĂŶĚĂŬĞƌ,ƵŐŚĞƐ/^W,͘
Ă͘ ƉƉƌŽdžŝŵĂƚĞůĞŶŐƚŚŽĨƉĂĐŬĞƌƐǁŝƚŚƐƉĂĐĞƌƉŝƉĞŝƐΕϰϬͲϱϬ͛ ƚŽƐƚƌĂĚĚůĞƉĞƌĨŽƌĂƚĞĚũŽŝŶƚĂŶĚ
ƚƌĞĂƚD ͘
ϭϲ͘ ŽŶĨŝƌŵǁĞůůŝƐĚĞĂĚ͘ůĞĞĚĂŶLJƉƌĞƐƐƵƌĞŽĨĨƚŽƌĞƚƵƌŶƚĂŶŬ͘<ŝůůǁĞůůǁͬ<t&͕ϴ͘ϯϯƉƉŐƐŽƵƌĐĞ
ǁĂƚĞƌŽƌϴ͘ϱƉƉŐ ĂƐŶĞĞĚĞĚ͘DĂŝŶƚĂŝŶŚŽůĞĨŝůůƚĂŬŝŶŐƌĞƚƵƌŶƐƚŽƚĂŶŬƵŶƚŝůůƵďƌ ŝĐĂƚŽƌĐŽŶŶĞĐƚŝŽŶŝƐ
ƌĞͲĞƐƚĂďůŝƐŚĞĚ͘&ůƵŝĚƐŵĂŶͲǁĂƚĐŚŵƵƐƚďĞƉĞƌĨŽƌŵĞĚǁŚŝůĞĚĞƉůŽLJŝŶŐ ĂŬĞƌ,ƵŐŚĞƐ/^W, ƚŽ
ĞŶƐƵƌĞƚŚĞǁĞůůƌĞŵĂŝŶƐŬŝůůĞĚĂŶĚƚŚĞƌĞ ŝƐŶŽĞdžĐĞƐƐĨůŽǁ͘
ϭϳ͘ ΎWĞƌĨŽƌŵĚƌŝůůďLJƉŝĐŬŝŶŐƵƉƐĂĨĞƚLJũŽŝŶƚǁŝƚŚd/tǀĂůǀĞĂŶĚƐƉĂĐĞŽƵƚďĞĨŽƌĞDh ĂŬĞƌ,ƵŐŚĞƐ/^W
,͘ZĞǀŝĞǁǁĞůůĐŽŶƚƌŽůƐƚĞƉƐǁŝƚŚĐƌĞǁƉƌŝŽƌƚŽďƌĞĂŬŝŶŐůƵďƌŝĐĂƚŽƌĐŽŶŶĞĐƚŝŽŶĂŶĚĐŽŵŵĞŶĐŝŶŐ
ŵĂŬĞƵƉŽĨ ϱϬ͛ĂŬĞƌ,ƵŐŚĞƐ/^W,͘KŶĐĞƚŚĞƐĂĨĞƚLJũŽŝŶƚĂŶĚd/tǀĂůǀĞŚĂǀĞďĞĞŶƐƉĂĐĞĚ ŽƵƚ͕
ŬĞĞƉƚŚĞƐĂĨĞƚLJũŽŝŶƚͬd/tǀĂůǀĞƌĞĂĚŝůLJĂĐĐĞƐƐŝďůĞŶĞĂƌƚŚĞǁŽƌŬŝŶŐƉůĂƚĨŽƌŵĨŽƌƋƵŝĐŬĚĞƉůŽLJŵĞŶƚŝĨ
ŶĞĐĞƐƐĂƌLJ͘
ϭϴ͘ƌĞĂŬůƵďƌŝĐĂƚŽƌĐŽŶŶĞĐƚŝŽŶĂƚYd^ĂŶĚďĞŐŝŶŵĂŬĞƵƉŽĨ d͕d͕ĂŶĚĂŬĞƌ,ƵŐŚĞƐ/^W, ǁŝƚŚ
ƐƉĂĐĞƌƉŝƉĞ͘ŽŶƐƚĂŶƚůLJŵŽŶŝƚŽƌĨůƵŝĚƌĂƚĞƐƉƵŵƉĞĚŝŶĂŶĚĨůƵŝ ĚƌĞƚƵƌŶƐŽƵƚŽĨƚŚĞǁĞůů͘&ůƵŝĚƐ
ŵĂŶͲǁĂƚĐŚŵƵƐƚďĞƉĞƌĨŽƌŵĞĚǁŚŝůĞĚĞƉůŽLJŝŶŐ ĞdžƚĞŶĚĞĚ, ƚŽĞŶƐƵƌĞƚŚĞǁĞůůƌĞŵĂŝŶƐŬŝůůĞĚ
ĂŶĚƚŚĞƌĞŝƐŶŽĞdžĐĞƐƐĨůŽǁ͘
ϭϵ͘ Z/,ĂŶĚĐŽƌƌĞůĂƚĞƚŽĨůĂŐƐ͕^Ğƚ ĂŬĞƌ/^W ƉĞƌK ĚĞƉƚŚƐƉŝĐŬĞĚĨƌŽŵ/WZK&͘
ϮϬ͘ ŽŶĨŝƌŵǁŝƚŚƉƵŵƉŝŶŐĐƌĞǁƚŚĂƚƚŚĞLJĂƌĞƌĞĂĚLJƚŽŵŝdž ĞŵĞŶƚͬ'Ğů ĨŽƌƉƵŵƉŝŶŐ͘
/WZK&ͬD dƌĞĂƚŵĞŶƚ
tĞůů͗ DW/ͲϯϬ
ĂƚĞ͗ ϲͬϮϳͬϮϮ
Ϯϭ͘ KŶĐĞŽŶĚĞƉƚŚ͕ƐĞƚƚŚĞůŽǁĞƌƚƌĞĂƚŵĞŶƚƉĂĐŬĞƌ;ŵŝĚͲĞůĞŵĞŶƚͿĂƚϱ͛ďĞůŽǁƚŚĞ ƉĞƌĨŽƌĂƚĞĚ ũŽŝŶƚƚŽ
ďĞƚƌĞĂƚĞĚ͘
ϮϮ͘ WƵŵƉďĂůůƚŽƐĞĂƚŝŶƚŚĞ/ŶũĞĐƚŝŽŶŽŶƚƌŽůsĂůǀĞ;/sͿ͘KŶĐĞďĂůůŽŶƐĞĂƚ͕ƉƌĞƐƐƵƌĞƵƉĂŶĚďŽƚŚ
ƉĂĐŬĞƌƐǁŝůůŝŶĨůĂƚĞ͘
Ϯϯ͘ ŽŶƚŝŶƵĞƚŽƉƌĞƐƐƵƌĞƵƉĂŶĚŵŽŶŝƚŽƌƉƌĞƐƐƵƌĞĨŽƌƐƚĂƌƚŽĨŝŶũĞĐƚŝŽŶ͘dŚĞdƌĞĂƚŵĞŶƚsĂůǀĞŝƐƐĞƚƚŽ
ĂůůŽǁŝŶũĞĐƚŝŽŶĂƚϲϬϬƉƐŝŽǀĞƌĨŽƌŵĂƚŝŽŶƉƌĞƐƐƵƌĞ;,W dĨƌŽŵ/WZK&ďĂƐĞůŝŶĞ ƉƐŝнƚŽŽůϲϬϬƉƐŝ ʹ
ϭϳϮϬ ŚLJĚƌŽƐƚĂƚŝĐƉƐŝс ^ƵƌĨĂĐĞƉƌĞƐƐƵƌĞͿ͘
Ă͘ WĂĐŬĞƌƐǁŝůůŶŽƚƌĞůĞĂƐĞǁŝƚŚƐŚƵƚƚŝŶŐĚŽǁŶŽĨƉƵŵƉƐ͘WĂĐŬĞƌƐĂƌĞƐĞƚƚŽƌĞůĞĂƐĞǁŚĞŶ
ďůĞĞĚŝŶŐŽĨĨƚŚĞŝŶŶĞƌƌĞĞůǀĂůǀĞƚŽƌĞůĞĂƐĞĂůůdƉƌĞƐƐƵƌĞ͘ ŽŶĨŝƌŵǁŝƚŚƚŽŽůŚĂŶĚŚŽǁ
ŵƵĐŚǁƚĐĂŶďĞƐĞƚͬƉƵůůĞĚƚŽĐŽŶĨŝƌŵŐŽŽĚƐĞƚ͘
Ϯϰ͘ ĞŐŝŶŝŶũĞĐƚŝŶŐϯй<ůǁĂƚĞƌĚŽǁŶƚŚĞdĨŽƌďĂƐĞůŝŶĞŝŶũĞĐƚŝǀŝƚLJ͘
Ă͘ dĂƌŐĞƚϳϬϬƉƐŝŐdƉƌĞƐƐƵƌĞ͘/ŶũĞĐƚĨŽƌĂŵŝŶŝŵƵŵϯϬŵŝŶƵƚĞƐƚŽĞƐƚĂďůŝƐŚĂďĂƐĞůŝŶĞ͘
ď͘ E ϳϬϬƉƐŝŐĐŽŝůĞĚƚƵďŝŶŐ ŝŶũĞĐƚŝŽŶƉƌĞƐƐƵƌĞ͘
Ϯϱ͘ ŽŶƚĂĐƚK ǁŝƚŚŝŶũĞĐƚŝǀŝƚLJƌĞƐƵůƚƐ͘͘
Ϯϲ͘ Dŝdž ϭϮ ďďůƐŽĨ ĞŵĞŶƚĂŶĚŽƌ'Ğů ĂŶĚƉƵŵƉƚŽĨŽƌŵĂƚŝŽŶ͘
Ă͘ sŽůƵŵĞĂƐƐƵŵƉƚŝŽŶƐ͗
ŝ͘ Ϭ͘ϬϱďďůͬĨƚĂŶŶƵůĂƌŚŽůĞǀŽůƵŵĞĨŽƌϴ͘ϱ͟ŚŽůĞĂŶĚϰ͘ϱ͟>ŝŶĞƌ͘
ŝŝ͘ ϭϮ ďďůƐŽĨĂŶŶƵůĂƌŚŽůĞǀŽůƵŵĞďĞƚǁĞĞŶ ƚŚĞŶĞdžƚϮƉĞƌĨŽƌĂƚĞĚůŝŶĞƌ
ŝŝŝ͘ DŽŶŝƚŽƌ /ͲϮϵ͛Ɛ ǁĞůůƉĞƌĨŽƌŵĂŶĐĞǁŚŝůĞƉƵŵƉŝŶŐƚŚĞũŽďĨŽƌĂŶŝŶĚŝĐĂƚŝŽŶŽĨ
ŝƐŽůĂƚŝŶŐƚŚĞ D
Ϯϳ͘ WƵŵƉ ĞŵĞŶƚͬ'Ğů ĂƐƐůŽǁĂƐƉƌĂĐƚŝĐĂďůĞƚŽƌĞĚƵĐĞĨƌĂĐƚƵƌĞƉŽƚĞŶƚŝĂůĂŶĚĂůůŽǁĨŽƌ ŝƚ ƚŽƚĂŬĞƚŚĞ
ƉĂƚŚŽĨůĞĂƐƚƌĞƐŝƐƚĂŶĐĞŝŶƚŽƚŚĞD ĨĞĂƚƵƌĞ͘E Ϭ͘ϳ WD͘
Ϯϴ͘ ŝƐƉůĂĐĞǁĂƚĞƌϭďďůƉĂƐƚ ůŝŶĞƌ ŝŶƚŽĨŽƌŵĂƚŝŽŶƚŽĐůĞĂƌƚŚĞǁĞůůďŽƌĞ͘
Ă͘ ŝƐĐƵƐƐǁͬĞŶŐŝŶĞĞƌĐŽŶƚŝŶŐĞŶĐLJƉůĂŶƐŝĨƐĐƌĞĞŶŽƵƚͬĨŽƌŵĂƚŝŽŶůŽĐŬƵƉŽĐĐƵƌƐĨŽƌŚŽǁŵƵĐŚ
ĞŵĞŶƚͬ'Ğů ŝƐƉůĂĐĞĚĂŶĚŝĨƚŽďůĞĞĚdƉƌĞƐƐƵƌĞƚŽƌĞůĞĂƐĞƉĂĐŬĞƌƐĂŶĚũĞƚŽƵƚŽƌƚŽ
ŚĞƐŝƚĂƚŝŽŶƐƋƵĞĞnjĞŝŶƚŽƉůĂĐĞ͘
Ϯϵ͘ ĨƚĞƌĚŝƐƉůĂĐĞŵĞŶƚŽĨƚŚĞ ĞŵĞŶƚͬ'Ğů͕ƌĞĚƵĐĞĨůƵŝĚŝŶũĞĐƚŝŽŶŝŶƚŽƚŚĞǁĞůůĂƐŵƵĐŚĂƐƉŽƐƐŝďůĞ͘
ϯϬ͘ ůĞĞĚŽĨĨdƉƌĞƐƐƵƌĞĨƌŽŵŝŶŶĞƌƌĞĞůǀĂůǀĞƚŽƌĞůĞĂƐĞƚŚĞƉĂĐŬĞƌƐ͘ůůŽǁƚŚĞĞůĂƐƚŽŵĞƌƐƚŽƌĞůĂdž
ƉƌŝŽƌƚŽƉƵůůŝŶŐƵƉͲŚŽůĞ͘
ϯϭ͘ ZĞƉĞĂƚƚƌĞĂƚŵĞŶƚ;ƐƚĞƉƐη ϭϵͲϯϬͿ ĨŽƌ ŽƚŚĞƌŝŶƚĞƌǀĂůƐŝĨŶĞĞĚĞĚ͘
ϯϮ͘ WKK,ƚŽϮ͕ϬϬϬ͛D͘&ƌĞĞnjĞƉƌŽƚĞĐƚǁĞůů͕ĐŝƌĐƵůĂƚŝŶŐĨůƵŝĚŝŶĂƚϭ͗ϭƌĞƚƵƌŶƐǁŚŝůĞĂĐĐŽƵŶƚŝŶŐĨŽƌƉŝƉĞ
ĚŝƐƉůĂĐĞŵĞŶƚ͘
ϯϯ͘ <ĞĞƉǁĞůů^/ĂŶĚĐŽŶƚĂĐƚK ƉƌŝŽƌƚŽƌĞƚƵƌŶŝŶŐƚŚĞǁĞůůƚŽŝŶũĞĐƚŝŽŶ͘
ϯϰ͘ ZDKŽŝůĞĚdƵďŝŶŐ
ƚƚĂĐŚŵĞŶƚƐ͗
ϭ͘ ƵƌƌĞŶƚtĞůůďŽƌĞ^ĐŚĞŵĂƚŝĐ
Ϯ͘ WƌŽƉŽƐĞĚ^ĐŚĞŵĂƚŝĐ
ϯ͘ ŽŝůdƵďŝŶŐKW ^ĐŚĞŵĂƚŝĐ
ϰ͘ ^ƚĂŶĚŝŶŐKƌĚĞƌƐĨŽƌKƉĞŶ,ŽůĞtĞůůŽŶƚƌŽůĚƵƌŝŶŐWĞƌĨ'ƵŶĞƉůŽLJŵĞŶƚ
ϱ͘ ƋƵŝƉŵĞŶƚ>ĂLJŽƵƚŝĂŐƌĂŵ
&RQILUPZHOOLVGHDGEHIRUHEUHDNLQJ3&(5HYLHZZHOOFRQWUROVWHSVDQGVWDQGLQJRUGHUVZLWKFUHZSULRUWREUHDNLQJ
OXEULFDWRUFRQQHFWLRQ(QVXUHVDIHW\MRLQWDQG7,:YDOYHDVVHPEO\DUHRQKDQGEHIRUHEUHDNLQJ3&(/'%+$
PJU
/WZK&ͬD dƌĞĂƚŵĞŶƚ
tĞůů͗ DW/ͲϯϬ
ĂƚĞ͗ ϲͬϮϳͬϮϮ
ŽŝůĞĚdƵďŝŶŐKWƐ
^ƚĂŶĚŝŶŐKƌĚĞƌƐĨŽƌKƉĞŶ,ŽůĞtĞůůŽŶƚƌŽůĚƵƌŝŶŐWĞƌĨ'ƵŶĞƉůŽLJŵĞŶƚ
/WZK&ͬD dƌĞĂƚŵĞŶƚ
tĞůů͗ DW/ͲϯϬ
ĂƚĞ͗ ϲͬϮϳͬϮϮ
/WZK&ͬD dƌĞĂƚŵĞŶƚ
tĞůů͗ DW/ͲϯϬ
ĂƚĞ͗ ϲͬϮϳͬϮϮ
ƋƵŝƉŵĞŶƚ>ĂLJŽƵƚŝĂŐƌĂŵ
BBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBBB
ZĞǀŝƐĞĚLJ͗:E>ϱͬϯϭͬϮϬϮϮ
WĂŐĞϭŽĨϮ
^, Dd/
DŝůŶĞWŽŝŶƚhŶŝƚ
tĞůů͗DWh/ͲϯϬ
>ĂƐƚŽŵƉůĞƚĞĚ͗ϱͬϮϯͬϮϬϮϮ
Wd͗ϮϮϮͲϬϮϯ
^/E' d/>
^ŝnjĞ dLJƉĞ tƚͬ'ƌĂĚĞͬŽŶŶ ƌŝĨƚ/ dŽƉ ƚŵ W&
ϮϬΗ ŽŶĚƵĐƚŽƌ ϭϮϵ͘ϱͬyͲϱϮͬtĞůĚ Eͬ ^ƵƌĨĂĐĞ ϭϯϱ͛ Eͬ
ϵͲϱͬϴΗ ^ƵƌĨĂĐĞ ϰϳͬ>ͲϴϬͬdyW ϴ͘ϱϮϱ͟ ^ƵƌĨĂĐĞ Ϯ͕ϭϲϭ͛ Ϭ͘ϬϳϯϮ
ϵͲϱͬϴΗ ^ƵƌĨĂĐĞ ϰϬͬ>ͲϴϬͬdyW ϴ͘ϲϳϵ͟ Ϯ͕ϭϲϭ͛ ϲ͕Ϭϳϰ͛ Ϭ͘Ϭϳϱϴ
ϰͲϭͬϮ͟ >ŝŶĞƌƐŽůŝĚͬƐůŽƚƚĞĚ ϭϯ͘ϱͬ>ͲϴϬͬ,LJĚϲϮϱ ϯ͘ϵϮϬ͟ ϲ͕ϭϭϬ͛ ϭϲ͕ϱϬϬ͛ Ϭ͘Ϭϭϰϵ
dh/E' d/>
ϯͲϭͬϮΗ dƵďŝŶŐ ϵ͘ϯͬ>ͲϴϬͬ h ϴZ Ϯ͘ϴϲϳ͟ ^ƵƌĨĂĐĞ ϲ͕ϭϭϱ͛ Ϭ͘ϬϬϴϳ
KW E,K> ͬ D Ed d/>
ƌŝǀĞŶ ϮϬ͟ŽŶĚƵĐƚŽƌ
ϭϮͲϭͬϰΗ ^ƚŐϭʹ>ĞĂĚϱϬϰƐdžͬdĂŝůϰϬϬƐdž
^ƚŐϮʹ>ĞĂĚϳϭϭƐdžͬdĂŝůϮϳϬƐdž
ϴͲϭͬϮ͟ ĞŵĞŶƚůĞƐƐ/ŶũĞĐƚŝŽŶ>ŝŶĞƌ
dZ Θt >>,
dƌĞĞ ĂŵĞƌŽŶϯϭͬϴΗϱDǁͬϯͲϭͬϴ͟ϱDĂŵĞƌŽŶtŝŶŐ
tĞůůŚĞĂĚ ĂŵĞƌŽŶϭϭ͟ϱ<džƐůŝƉůŽĐŬďŽƚƚŽŵǁͬ;ϮͿϮͲϭͬϭϲ͟ϱ<ŽƵƚƐ
' E Z>t >>/E&K
W/η͗ϱϬͲϬϮϵͲϮϯϳϭϬͲϬϬͲϬϬ
ŽŵƉůĞƚŝŽŶĂƚĞ͗ϱͬϮϯͬϮϬϮϮ
t >>/E>/Ed/KE d/>
<KWΛϭϮϱ͛
DĂdž,ŽůĞŶŐůĞсϵϱΣΛϴ͕Ϭϭϱ͛D
dсϭϲ͕ϱϬϬ͛;DͿͬdсϰ͕ϭϯϯ͛;dsͿ
ϮϬ͟
KƌŝŐ͘< ůĞǀ͗͘ϲϳ͘ϱϵ͛ͬ'> ůĞǀ͗͘ϯϯ͘ϴ͛
ϯͲϭͬϮ͟
ϵͲϱͬϴ͟
6HH
'ULOOHG
/LQHU
'HWDLO
Wdсϭϲ͕ϱϬϬ͛;DͿͬWdсϰ͕ϭϯϯ͛;dsͿ
´ µ(6¶
&HPHQWHU#
¶
ϰͲϭͬϮ͟
: t >Zz d/>
EŽ dŽƉD /ƚĞŵ
/
hƉƉĞƌŽŵƉůĞƚŝŽŶ
ϭϱ͕Ϭϰϱ͛ĞŶŝƚŚ'ĂƵŐĞ
Ϯ Εϲ͕ϬϮϱ͛ yEEŝƉƉůĞ͕Ϯ͘ϴϭϯ͕͟Ϯ͘ϳϱ͟EŽͲ'Ž Ϯ͘ϳϱϬ͟
ϯ Εϲ͕ϭϭϱ͛ >ŽĐĂƚĞƌ^Ƶď͕ϴ͘Ϯϱ͟EŽ'Ž;ďŽƚƚŽŵŽĨůŽĐĂƚŽƌƐƉĂĐĞĚŽƵƚϭ͘ϳϬ͛Ϳ ϲ͘ϭϲϬ͟
ϰ Εϲ͕ϭϭϱ͛ ƵůůĞƚ^ĞĂůƐʹdyWdŽƉŽdždžDƵůĞ^ŚŽĞ ϲ͘ϭϲϬ͟
>ŽǁĞƌŽŵƉůĞƚŝŽŶ
ϱ ϱ͕ϴϲϱ͛ ϵͲϱͬϴ͟^>yW>ŝŶĞƌdŽƉWĂĐŬĞƌ ϲ͘ϮϭϬ͟
ϲ ϭϲ͕ϰϵϴ͛ ^ŚŽĞ
DŝůŶĞWŽŝŶƚhŶŝƚ
tĞůů͗DWh/ͲϯϬ
>ĂƐƚŽŵƉůĞƚĞĚ͗ϱͬϮϯͬϮϬϮϮ
Wd͗ϮϮϮͲϬϮϯ
ZĞǀŝƐĞĚLJ͗:E>ϱͬϯϭͬϮϬϮϮ
WĂŐĞϮŽĨϮ
´'ULOOHG/LQHU
:ƚƐ dŽƉ;DͿ dŽƉ;dsͿ ƚŵ;DͿ ƚŵ;dsͿ
ϭ ϲϬϵϮ͛ ϯϵϰϴ͛ ϲϭϯϰ͛ ϯϵϰϵ͛
ϭ ϲϮϭϰ͛ ϯϵϰϴ͛ ϲϮϱϱ͛ ϯϵϰϳ͛
ϭ ϲϯϯϳ͛ ϯϵϰϰ͛ ϲϯϳϴ͛ ϯϵϰϯ͛
ϭ ϲϰϲϭ͛ ϯϵϯϵ͛ ϲϱϬϭ͛ ϯϵϯϳ͛
ϭ ϲϱϴϯ͛ ϯϵϯϲ͛ ϲϲϮϯ͛ ϯϵϯϲ͛
ϭ ϲϳϬϰ͛ ϯϵϯϴ͛ ϲϳϰϰ͛ ϯϵϯϵ͛
ϭ ϳϰϯϮ͛ ϯϵϱϴ͛ ϳϰϳϯ͛ ϯϵϲϬ͛
ϭ ϳϱϱϱ͛ ϯϵϲϱ͛ ϳϱϵϰ͛ ϯϵϲϳ͛
ϭ ϳϲϳϲ͛ ϯϵϲϵ͛ ϳϳϭϲ͛ ϯϵϲϵ͛
ϭ ϴϬϰϭ͛ ϯϵϱϭ͛ ϴϬϴϬ͛ ϯϵϰϴ͛
ϭ ϴϰϬϳ͛ ϯϵϯϱ͛ ϴϰϰϳ͛ ϯϵϯϲ͛
ϭ ϴϱϯϬ͛ ϯϵϯϴ͛ ϴϱϳϬ͛ ϯϵϰϬ͛
ϭ ϴϲϱϬ͛ ϯϵϰϯ͛ ϴϲϵϬ͛ ϯϵϰϬ͛
ϭ ϴϳϳϬ͛ ϯϵϰϵ͛ ϴϴϬϳ͛ ϯϵϱϮ͛
ϭ ϴϴϴϴ͛ ϯϵϱϳ͛ ϴϵϮϳ͛ ϯϵϱϵ͛
ϭ ϵϬϬϳ͛ ϯϵϲϭ͛ ϵϬϰϴ͛ ϯϵϲϭ͛
ϭ ϵϭϮϵ͛ ϯϵϲϮ͛ ϵϭϲϲ͛ ϯϵϲϮ͛
ϭ ϵϮϰϵ͛ ϯϵϲϰ͛ ϵϮϴϵ͛ ϯϵϲϱ͛
ϭ ϵϯϳϮ͛ ϯϵϲϵ͛ ϵϰϭϮ͛ ϯϵϳϭ͛
ϭ ϵϰϵϱ͛ ϯϵϳϱ͛ ϵϱϯϱ͛ ϯϵϳϳ͛
ϭ ϵϲϭϳ͛ ϯϵϴϭ͛ ϵϲϱϴ͛ ϯϵϴϯ͛
ϭ ϵϳϰϭ͛ ϯϵϴϱ͛ ϵϳϴϭ͛ ϯϵϴϱ͛
ϭ ϵϴϲϰ͛ ϯϵϴϱ͛ ϵϵϬϰ͛ ϯϵϴϱ͛
ϭ ϵϵϴϲ͛ ϯϵϴϱ͛ ϭϬϬϮϳ͛ ϯϵϴϱ͛
ϭ ϭϬϭϭϬ͛ ϯϵϴϱ͛ ϭϬϭϱϭ͛ ϯϵϴϱ͛
ϭ ϭϬϮϯϱ͛ ϯϵϴϳ͛ ϭϬϮϳϱ͛ ϯϵϴϴ͛
ϭ ϭϬϯϱϵ͛ ϯϵϵϬ͛ ϭϬϯϵϵ͛ ϯϵϵϭ͛
ϭ ϭϬϰϳϵ͛ ϯϵϵϯ͛ ϭϬϱϭϵ͛ ϯϵϵϯ͛
ϭ ϭϬϲϬϭ ϯϵϵϱ͛ ϭϬϲϰϭ͛ ϯϵϵϱ͛
ϭ ϭϬϳϮϰ͛ ϯϵϵϳ͛ ϭϬϳϲϰ͛ ϯϵϵϳ͛
ϭ ϭϬϴϰϲ͛ ϯϵϵϵ͛ ϭϬϴϴϳ͛ ϰϬϬϬ͛
ϭ ϭϬϵϲϴ͛ ϰϬϬϰ͛ ϭϭϬϬϵ͛ ϰϬϬϲ͛
ϭ ϭϭϬϵϮ͛ ϰϬϭϬ͛ ϭϭϭϯϯ͛ ϰϬϭϯ͛
ϭ ϭϭϮϭϱ͛ ϰϬϭϳ͛ ϭϭϮϱϲ͛ ϰϬϭϵ͛
ϭ ϭϭϯϯϵ͛ ϰϬϮϯ͛ ϭϭϯϳϵ͛ ϰϬϮϰ͛
ϭ ϭϭϰϲϬ͛ ϰϬϮϱ͛ ϭϭϱϬϭ͛ ϰϬϮϱ͛
ϭ ϭϭϱϴϭ͛ ϰϬϮϱ͛ ϭϭϲϮϭ͛ ϰϬϮϱ͛
ϭ ϭϭϳϬϯ͛ ϰϬϮϲ͛ ϭϭϳϰϰ͛ ϰϬϮϲ͛
ϭ ϭϭϴϮϱ͛ ϰϬϮϴ͛ ϭϭϴϲϱ͛ ϰϬϮϵ͛
ϭ ϭϭϵϰϴ͛ ϰϬϯϭ͛ ϭϭϵϴϵ͛ ϰϬϯϮ͛
ϭ ϭϮϬϳϭ͛ ϰϬϯϱ͛ ϭϮϭϭϮ͛ ϰϬϯϳ͛
ϭ ϭϮϭϵϱ͛ ϰϬϰϬ͛ ϭϮϮϯϰ͛ ϰϬϰϮ͛
ϭ ϭϮϯϭϴ͛ ϰϬϰϰ͛ ϭϮϯϱϵ͛ ϰϬϰϱ͛
ϭ ϭϮϰϰϯ͛ ϰϬϰϳ͛ ϭϮϰϴϯ͛ ϰϬϰϴ͛
ϭ ϭϮϱϲϳ͛ ϰϬϱϬ͛ ϭϮϲϬϴ͛ ϰϬϱϭ͛
ϭ ϭϮϲϴϴ͛ ϰϬϱϮ͛ ϭϮϳϮϳ͛ ϰϬϱϭ͛
ϭ ϭϮϴϬϰ͛ ϰϬϱϬ͛ ϭϮϴϰϲ͛ ϰϬϰϴ͛
ϭ ϭϮϵϮϮ͛ ϰϬϰϲ͛ ϭϮϵϲϯ͛ ϰϬϰϱ͛
ϭ ϭϯϬϰϭ͛ ϰϬϰϯ͛ ϭϯϬϴϮ͛ ϰϬϰϮ͛
ϭ ϭϯϭϱϵ͛ ϰϬϰϮ͛ ϭϯϭϵϵ͛ ϰϬϰϮ͛
ϭ ϭϯϮϴϰ͛ ϰϬϰϰ͛ ϭϯϯϮϰ͛ ϰϬϰϱ͛
ϭ ϭϯϰϬϳ͛ ϰϬϰϵ͛ ϭϯϰϰϳ͛ ϰϬϱϭ͛
ϭ ϭϯϱϯϭ͛ ϰϬϱϰ͛ ϭϯϱϳϭ͛ ϰϬϱϲ͛
ϭ ϭϯϲϱϯ͛ ϰϬϱϲ͛ ϭϯϲϵϯ͛ ϰϬϲϬ͛
ϭ ϭϯϳϳϱ͛ ϰϬϲϮ͛ ϭϯϴϭϱ͛ ϰϬϲϯ͛
ϭ ϭϯϴϵϰ͛ ϰϬϲϰ͛ ϭϯϵϯϯ͛ ϰϬϲϱ͛
ϭ ϭϰϬϭϴ͛ ϰϬϲϲ͛ ϭϰϬϱϴ͛ ϰϬϲϲ͛
ϭ ϭϰϭϰϭ͛ ϰϬϲϲ͛ ϭϰϭϴϮ͛ ϰϬϲϳ͛
ϭ ϭϰϮϲϲ͛ ϰϬϲϴ͛ ϭϰϯϬϲ͛ ϰϬϲϵ͛
ϭ ϭϰϯϴϵ͛ ϰϬϳϮ͛ ϭϰϰϯϬ͛ ϰϬϳϯ͛
ϭ ϭϰϱϭϬ͛ ϰϬϳϱ͛ ϭϰϱϱϭ͛ ϰϬϳϱ͛
ϭ ϭϰϲϮϴ͛ ϰϬϳϱ͛ ϭϰϲϲϴ͛ ϰϬϳϱ͛
ϭ ϭϰϳϰϲ͛ ϰϬϳϳ͛ ϭϰϳϴϲ͛ ϰϬϳϵ͛
ϭ ϭϰϴϲϯ͛ ϰϬϴϰ͛ ϭϰϵϬϰ͛ ϰϬϴϳ͛
ϭ ϭϰϵϴϮ͛ ϰϬϵϯ͛ ϭϱϬϮϯ͛ ϰϬϵϱ͛
ϭ ϭϱϮϭϱ͛ ϰϭϬϲ͛ ϭϱϮϱϲ͛ ϰϭϬϴ͛
ϭ ϭϱϯϯϴ͛ ϰϭϭϯ͛ ϭϱϯϳϴ͛ ϰϭϭϱ͛
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:ƚƐ dŽƉ;DͿ dŽƉ;dsͿ ƚŵ;DͿ ƚŵ;dsͿ
1a. Well Status:Oil SPLUG Other Abandoned Suspended
1b. Well Class:
20AAC 25.105 20AAC 25.110 Development Exploratory
GINJ WINJ WDSPL No. of Completions: _1 Service Stratigraphic Test
2. Operator Name: 6. Date Comp., Susp., or 14. Permit to Drill Number / Sundry:
Aband.:
3. Address: 7. Date Spudded: 15. API Number:
4a. Location of Well (Governmental Section): 8. Date TD Reached: 16. Well Name and Number:
Surface:
Top of Productive Interval: 9. Ref Elevations: KB: 17. Field / Pool(s):
GL: 33.8' BF:
Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation:
4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth MD/TVD: 19. DNR Approval Number:
Surface: x- y- Zone- 4
TPI: x- y- Zone- 4 12. SSSV Depth MD/TVD: 20. Thickness of Permafrost MD/TVD:
Total Depth: x- y- Zone- 4
5. Directional or Inclination Survey: Yes (attached) No 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD:
Submit electronic information per 20 AAC 25.050 (ft MSL)
22.Logs Obtained:
23.
BOTTOM
20" X-52 158'
L-80 1907'
L-80 3948'
4-1/2" L-80 4133'
24. Open to production or injection? Yes No 25.
26.
Was hydraulic fracturing used during completion? Yes No
DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED
27.
Date First Production: Method of Operation (Flowing, gas lift, etc.):
Hours Tested: Production for Gas-MCF:
Test Period
Casing Press: Calculated Gas-MCF: Oil Gravity - API (corr):
Press. 24-Hour Rate
9-5/8"12-1/4"
ACID, FRACTURE, CEMENT SQUEEZE, ETC.
CASING, LINER AND CEMENTING RECORD
List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data within 90 days of completion,
Uncemented Drilled Liner8-1/2"
TUBING RECORD
Liner Top Packer
6115'3-1/2" 9.3# L-80
SIZEIf Yes, list each interval open (MD/TVD of Top and Bottom; Perforation
Size and Number; Date Perfd):
Stg 2 L - 711 sx / T - 270 sx
Driven
33' 2161' Stg 1 L - 504 sx / T - 400 sx
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
WELL COMPLETION OR RECOMPLETION REPORT AND LOG
Hilcorp Alaska, LLC
WAG
Gas
3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503
5/22/2022
2333' FSL, 3771' FEL, Sec. 33, T13N, R10E, UM, AK
1798' FNL, 528' FWL, Sec. 21, T13N, R10E, UM, AK
222-023
Milne Point Field / Schrader Bluff Oil Pool
67.59'
16500' / 4133'
HOLE SIZE AMOUNT
PULLED
50-029-23710-00-00
MPU I-30
551600 6009448
1625' FNL, 1362' FEL, Sec. 32, T13N, R10E, UM, AK
CEMENTING RECORD
6010750
SETTING DEPTH TVD
6021148
BOTTOM TOP
33'
33'
CASING WT. PER
FT.GRADE
13.5#
548716
550507
TOP
SETTING DEPTH MD
33'
6110'
Per 20 AAC 25.283 (i)(2) attach electronic information
40#
16500'
1907'
3949'
DEPTH SET (MD)
5865' / 3936'
PACKER SET (MD/TVD)
129.5#
47#
158'
2161' 6074'
Gas-Oil Ratio:Choke Size:Water-Bbl:
PRODUCTION TEST
Not on Injection
Date of Test:
Flow Tubing
Oil-Bbl:
suspension, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray,
caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation
record. Acronyms may be used. Attach a separate page if necessary
N/A
4-1/2" Drilled Liner 5/19/2022
***Please see Schematic for Details***
ROP, AGR, DGR, ABG, EWR, ADR MD & TVD
Sr Res EngSr Pet GeoSr Pet Eng
Oil-Bbl: Water-Bbl:
5/16/2022
5/2/2022
ADL 025906, 025517, 025515 & 315848
88-004
N/AN/A
None
16500' / 4133'
Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment
By Meredith Guhl at 10:16 am, Jun 10, 2022
Completed
5/22/2022
MDG
RBDMS 6/10/2022 MDG
G
DSR-6/10/22SFD 11/2/2023MGR30AUG2022
Conventional Core(s): Yes No Sidewall Cores:
30.
MD TVD
37' 37'
2030' 1805'
Top of Productive Interval
1443' 1350'
2303' 2012'
4218' 3289'
4948' 3697'
5390' 3853'
5510' 3882'
5922' 3940'
SB OA 5922' 3940'
31. List of Attachments:
32. I hereby certify that the foregoing is true and correct to the best of my knowledge.
Contact Name: Joe Lastufka
Contact Email:joseph.lastufka@hilcorp.com
Authorized Contact Phone: 907-777-8400
General:
Item 1a:
Item 1b:
Item 4b:
Item 9:
Item 15:
Item 19:
Item 20:
Item 22:
Item 23:
Item 24:
Item 27:
Item 28:
Item 30:
Item 31: Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and
other tests as required including, but not limited to: core analysis, paleontological report, production or well test results.
Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29.
Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool.
If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the
producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced,
showing the data pertinent to such interval).
Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit
detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity,
permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology.
The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements
given in other spaces on this form and in any attachments.
The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00).
Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain).
Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical
laboratory information required by 20 AAC 25.071.
Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data within 90 days of completion,
suspension, or abandonment, whichever occurs first.
Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection,
Observation, or Other.
Formation at total depth:
Ugnu LA3
Signature w/Date:
Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY-123), Land Use Permit (LAS 12345),
and/or Easement (ADL 123456) number.
INSTRUCTIONS
Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each
segregated pool is a completion.
TPI (Top of Producing Interval).
Yes No
Well tested? Yes No
28. CORE DATA
If yes, list intervals and formations tested, briefly summarizing test results.
Attach separate pages to this form, if needed, and submit detailed test
information, including reports, per 20 AAC 25.071.
NAME
Schrader Bluff OA
Schrader Bluff NA
SV 5
SV 1
This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram
with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical
reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted.
Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis,
paleontological report, production or well test results, per 20 AAC 25.070.
If Yes, list formations and intervals cored (MD/TVD, From/To), and summarize lithology and presence of oil, gas or water (submit separate pages with this form,
if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071.
Authorized Name: Monty Myers
Authorized Title: Drilling Manager
Schrader Bluff OA
Schrader Bluff NF (Fault)
Permafrost - Base
29. GEOLOGIC MARKERS (List all formations and markers encountered): FORMATION TESTS
Permafrost - Top
Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment
6.9.2022Digitally signed by Monty M Myers
DN: cn=Monty M Myers, c=US,
o=Hilcorp Alaska, LLC, ou=Technical
Services - AK Drilling,
email=mmyers@hilcorp.com
Reason: I am approving this document
Date: 2022.06.09 15:44:44 -08'00'
Monty M
Myers
TPI
_____________________________________________________________________________________
Revised By: JNL 5/31/2022
Page1 of 2
SCHEMATIC
Milne Point Unit
Well: MPU I-30
Last Completed: 5/23/2022
PTD: 222-023
CASING DETAIL
Size Type Wt/ Grade/ Conn Drift ID Top Btm BPF
20" Conductor 129.5 / X-52 / Weld N/A Surface 135’ N/A
9-5/8" Surface 47 / L-80 / TXP 8.525” Surface 2,161’ 0.0732
9-5/8" Surface 40 / L-80 / TXP 8.679” 2,161’ 6,074’ 0.0758
4-1/2” Liner solid/slotted 13.5 / L-80 / Hyd 625 3.920” 6,110’ 16,500’ 0.0149
TUBING DETAIL
3-1/2" Tubing 9.3 / L-80 / EUE 8RD 2.867” Surface 6,115’ 0.0087
OPEN HOLE / CEMENT DETAIL
Driven 20” Conductor
12-1/4"Stg 1 –Lead 504 sx / Tail 400 sx
Stg 2 –Lead 711 sx / Tail 270 sx
8-1/2” Cementless Injection Liner
TREE & WELLHEAD
Tree Cameron 3 1/8" 5M w/ 3-1/8” 5M Cameron Wing
Wellhead Cameron 11” 5K x sliplock bottom w/ (2) 2-1/16” 5K outs
GENERAL WELL INFO
API#: 50-029-23710-00-00
Completion Date: 5/23/2022
WELL INCLINATION DETAIL
KOP @ 125’
Max Hole Angle = 95° @ 8,015’ MD
TD =16,500’(MD) / TD =4,133’(TVD)
20”
Orig. KB Elev.:67.59’ / GL Elev.:33.8’
3-1/2”
6
2
9-5/8”
1
3/4
See
Drilled
Liner
Detail
PBTD =16,500’(MD) / PBTD =4,133’(TVD)
9-5/8” ‘ES’
Cementer @
2,178’
4-1/2”
5
JEWELRY DETAIL
No Top MD Item
ID
Upper Completion
15,045’Zenith Gauge
2 ~6,025’ XN Nipple, 2.813”, 2.75” No-Go 2.750”
3 ~6,115’ Locater Sub, 8.25” No Go (bottom of locator spaced out 1.70’) 6.160”
4 ~6,115’ Bullet Seals – TXP Top Box x Mule Shoe 6.160”
Lower Completion
5 5,865’ 9-5/8” SLZXP Liner Top Packer 6.210”
6 16,498’ Shoe
Milne Point Unit
Well: MPU I-30
Last Completed: 5/23/2022
PTD: 222-023
Revised By: JNL 5/31/2022
Page 2 of 2
4-1/2” Drilled Liner
Jts Top (MD) Top (TVD) Btm (MD) Btm (TVD)
1 6092’ 3948’ 6134’ 3949’
1 6214’ 3948’ 6255’ 3947’
1 6337’ 3944’ 6378’ 3943’
1 6461’ 3939’ 6501’ 3937’
1 6583’ 3936’ 6623’ 3936’
1 6704’ 3938’ 6744’ 3939’
1 7432’ 3958’ 7473’ 3960’
1 7555’ 3965’ 7594’ 3967’
1 7676’ 3969’ 7716’ 3969’
1 8041’ 3951’ 8080’ 3948’
1 8407’ 3935’ 8447’ 3936’
1 8530’ 3938’ 8570’ 3940’
1 8650’ 3943’ 8690’ 3940’
1 8770’ 3949’ 8807’ 3952’
1 8888’ 3957’ 8927’ 3959’
1 9007’ 3961’ 9048’ 3961’
1 9129’ 3962’ 9166’ 3962’
1 9249’ 3964’ 9289’ 3965’
1 9372’ 3969’ 9412’ 3971’
1 9495’ 3975’ 9535’ 3977’
1 9617’ 3981’ 9658’ 3983’
1 9741’ 3985’ 9781’ 3985’
1 9864’ 3985’ 9904’ 3985’
1 9986’ 3985’ 10027’ 3985’
1 10110’ 3985’ 10151’ 3985’
1 10235’ 3987’ 10275’ 3988’
1 10359’ 3990’ 10399’ 3991’
1 10479’ 3993’ 10519’ 3993’
1 10601 3995’ 10641’ 3995’
1 10724’ 3997’ 10764’ 3997’
1 10846’ 3999’ 10887’ 4000’
1 10968’ 4004’ 11009’ 4006’
1 11092’ 4010’ 11133’ 4013’
1 11215’ 4017’ 11256’ 4019’
1 11339’ 4023’ 11379’ 4024’
1 11460’ 4025’ 11501’ 4025’
1 11581’ 4025’ 11621’ 4025’
1 11703’ 4026’ 11744’ 4026’
1 11825’ 4028’ 11865’ 4029’
1 11948’ 4031’ 11989’ 4032’
1 12071’ 4035’ 12112’ 4037’
1 12195’ 4040’ 12234’ 4042’
1 12318’ 4044’ 12359’ 4045’
1 12443’ 4047’ 12483’ 4048’
1 12567’ 4050’ 12608’ 4051’
1 12688’ 4052’ 12727’ 4051’
1 12804’ 4050’ 12846’ 4048’
1 12922’ 4046’ 12963’ 4045’
1 13041’ 4043’ 13082’ 4042’
1 13159’ 4042’ 13199’ 4042’
1 13284’ 4044’ 13324’ 4045’
1 13407’ 4049’ 13447’ 4051’
1 13531’ 4054’ 13571’ 4056’
1 13653’ 4056’ 13693’ 4060’
1 13775’ 4062’ 13815’ 4063’
1 13894’ 4064’ 13933’ 4065’
1 14018’ 4066’ 14058’ 4066’
1 14141’ 4066’ 14182’ 4067’
1 14266’ 4068’ 14306’ 4069’
1 14389’ 4072’ 14430’ 4073’
1 14510’ 4075’ 14551’ 4075’
1 14628’ 4075’ 14668’ 4075’
1 14746’ 4077’ 14786’ 4079’
1 14863’ 4084’ 14904’ 4087’
1 14982’ 4093’ 15023’ 4095’
1 15215’ 4106’ 15256’ 4108’
1 15338’ 4113’ 15378’ 4115’
1 15454’ 4120’ 15494’ 4122’
1 15579’ 4125’ 15619’ 4127’
1 15701’ 4128’ 15741’ 4128’
1 15823’ 4128’ 15863’ 4128’
1 15941’ 4128’ 15982’ 4128’
1 16060’ 4129’ 16100’ 4130’
1 16178’ 4132’ 16218’ 4134’
1 16295’ 4136’ 16336’ 4136’
1 16418’ 4135’ 16456’ 4134’
Jts Top (MD) Top (TVD) Btm (MD) Btm (TVD)
CASING AND LEAK-OFF FRACTURE TESTS
Well Name:MPU I-30 Date:5/11/2022
Csg Size/Wt/Grade:9.625"40# x 47#, L-80 Supervisor:Demoski/Vanderpool
Csg Setting Depth:6074 TMD 3947 TVD
Mud Weight:9.4 ppg LOT / FIT Press =534 psi
.
LOT / FIT =12.00 ppg Hole Depth =6104 md
Fluid Pumped=1.9 Bbls Volume Back =1.0 bbls
Estimated Pump Output:0.101 Barrels/Stroke
LOT / FIT DATA CASING TEST DATA
Enter Strokes Enter Pressure Enter Strokes Enter Pressure
Here Here Here Here
->00 ->00
->2146 ->5278
->4181 ->10 515
->6225 ->15 748
->8276 ->20 927
->10 315 ->25 1148
->12 357 ->30 1400
->13 385 ->35 1685
->14 415 ->40 1975
->15 440 ->45 2236
->16 473 ->48 2436
->17 493 ->50 2556
->18 518 ->52 2649
->19 536 ->
Enter Holding Enter Holding Enter Holding Enter Holding
Time Here Pressure Here Time Here Pressure Here
->0536 ->02649
->1530 ->52637
->2518 ->10 2630
->3503 ->15 2625
->4489 ->20 2621
->5477 ->25 2619
->6465 ->26 2618
->7453 ->27 2618
->8444 ->28 2617
->9433 ->29 2617
->10 424 ->30 2617
->11 415 ->
->12 406 ->
->13 398 ->
->14 390
->15 382
->
12.00 ppg
534
0
2 4
6
8 10 1213141516171819
0
5
10
15
20
25
30
35
40
45
48
50
52
0
100
200
300
400
500
600
700
800
900
1000
1100
1200
1300
1400
1500
1600
1700
1800
1900
2000
2100
2200
2300
2400
2500
2600
2700
2800
2900
3000
0102030405060
Pr
e
s
s
u
r
e
(
p
s
i
)
Strokes (# of)
LOT / FIT DATA CASING TEST DATA
Pr
e
s
s
u
r
e
(
p
s
i
)
536530518503489477465453444433424415406398390382
2649 2637 2630 2625 2621 261926182618261726172617
0
100
200
300
400
500
600
700
800
900
1000
1100
1200
1300
1400
1500
1600
1700
1800
1900
2000
2100
2200
2300
2400
2500
2600
2700
2800
2900
3000
0 5 10 15 20 25 30 35
Pr
e
s
s
u
r
e
(p
s
i
)
Time (Minutes)
LOT / FIT DATA CASING TEST DATA
Activity Date Ops Summary
4/30/2022 Complete I-30 pad inspection. Pull the rig off I-29 and move to the end of the pad. Remove the surface annular, diverter tee and knife valve from behind I-29. With
the crane install the diverter tee and surface annular. Set mats around well I-30 and lay out mats for the rig in front of the well. Spot surface riser, knife valve,
adapter spool, tree and wellhead equipment behind the well. Diverter test notification made on 4/30/22 at 18:57 hours. AOGCC inspector Brain Bixby waived
witness on 4/30/22 at 19:14 hours. Move the rig over I-30 and center over the well. Shim and level the rig PJSM. Skid the rig floor into drilling position. Work on rig
acceptance checklist. Set mats for the rock washer, slop tank and MPD shack. Hook up interconnects under the rig floor. Get steam going to the rig floor. Spot the
slop tank and rock washer. Spot the fuel trailer and DD/MWD shack. Work on rig acceptance checklist. NU the surface riser and knife valve. Align the diverter tee
to point out the cellar diverter door. NU diverter line.
5/1/2022 Work on rig acceptance checklist. Continue to RU installing diverter line. Spot the mud lab, 5-star and eviro-vac. Power up all shacks. Get comms operational. Set
water pump house. Install 90' mousehole. Hookup accumulator lines to bag and knife valve. Rig on high line at 10:30 hours. Welder install sumps in pits 3 and 4.
Install cleanout risers for same. Work on rig acceptance checklist. Continue to install diverter line. Load17 joints 5'' HWDP and 201 joints 5'' DP into the pipe shed
and process. Adjust the drag chain to rock washer. Set pump house and upright water tank. Mechanic performed TD inspection. Welder continues to install
cleanout risers in pits. Work on rig acceptance checklist. Continue to adjust the drag chain, install the diverter line and process 5" DP. PJSM. Slip and cut 94' of
drilling line (14 wraps). Simops: Continue to process 5" DP. Inspect the saver sub and grabber dies. Grabber dies are good. Changeout the saver sub. Lock ring
bolt for the IBOP sheared while tightening up. Several other bolts were elongated. Source new bolts. Simops: Continue to process 5" DP. Obtain RKBs. PU and MU
3 stands of 5" HWDP, 1 stand of 5" HWDP with jar and 2 stands of 5" HWDP for the BHA. Perform the diverter function test with 5" HWDP. The states right to
witness was waived by AOGCC inspector Brian Bixby via email on 4/30/22 at 19:14 hours. Knife valve opened in 21 seconds and the annular closed in 27seconds.
Start taking on spud mud at 05:30 hours. Accumulator Test: System pressure = 2950 psi. Pressure after closure = 1700 psi. 200 psi attained in 35 seconds. Full
pressure attained in 154 seconds. Nitrogen Bottles - 6 at 2100 psi. Rig electrician calibrated and tested the rig gas alarms. Diverter length = 455'. Nearest ignition
source of heat traced line is 84' way from the end of the diverter.
5/2/2022 Install all new lock ring bolts for the IBOP. Finish filling the pits with spud mud, Test totco PVT alarms. Flood stack and lines, no leaks. Finish up derrick inspection.
Rig accepted @ 06:00 MU BHA 1, 12 1/4'' Kymera bit, 1.5 deg mud motor and XO, Pre-spud meeting with all parties involved. Discussed well objectives and
surface hole hazards. Table top diverter drill - discussed all roles and responsibilities. Reviewed safe briefing areas and emergency notification. MU stand HW and
TD, Tag ice at 44'. Test mud lines and Geo Span lines to 250/3500 psi (good). Cleanout 20" conductor to 122' with water, pumping 400 gpm, 360 psi, 40 rpm, 1-2k
torque, drag chain quit and flow line started packing off. Swap to 8.8 spud mud on the fly. Work the pipe, circulate slow, jet and clear out flow line and get drag
chain operational, RU 2'' hose for an additional FL jet. Continue to cleanout the conductor to 135' pumping 400 gpm, 360 psi, 40 rpm, 1-2k torque. Drill 12-1/4"
surface hole from 135' to 167' with the drag chain stalling out. 400 GPM, 670 PSI, 40 RPM, 1-2K ft/lbs TQ, 2K WOB. 50K PU / 50K SO / 50K ROT. 8.8 ppg MW,
250 vis Work pipe, circulate at min rate, drag chain tension to tight, adjust and loosen same, drag chain running as it should. Drill 12-1/4" surface hole from 167' to
218' MD, 83' drilled. 400 GPM, 670 PSI, 40 RPM, 1-2K ft/lbs TQ, 2K WOB. 55K PU / 55K SO / 55K ROT. 8.8 ppg MW, 250 vis Circulate the hole clean, 400 gpm,
560 psi, 40 rpm, 1-2k tq, POOH racking back 2 stands of HW, BD TD, pull bit to surface, inspect same, good, PJSM with new Driller and crew on MU BHA, the rig
mechanic and electrician troubleshoot upper IBOP not functioning, no power. Found the valve on solenoid that operates actuator washed out, C/O same, function
tested good. MU Gyro While Drilling, directional, gamma, resistivity and flex collar to 129'. Initialize MWD tools. PU and MU NM flex collars to 162'. MU first stand
of HWDP. Obtain gyro survey at 162.7'. Wash down to 218' without difficulty (no fill observed). Drill 12-1/4" surface hole from 218' to 414' (414' TVD). Drilled 196'
= 65.3'/hr AROP. 398 GPM = 1,020 psi, 30 RPM = 0-5K ft/lbs torque, WOB = 0-5K, PU = 67K, SO = 60K, ROT = 65K. MW = 9.0 ppg, Vis = 188, ECD = 9.5 ppg,
max gas units = 0 Drill 12-1/4" surface hole from 414' to 906' (892' TVD). Drilled 492' = 82'/hr AROP. 402 GPM = 1,075 psi, 36 RPM = 3-5K ft/lbs torque, WOB = 5-
10K, PU = 82K, SO = 78K, ROT = 80K. MW = 9.15 ppg, Vis = 210, ECD = 10.0 ppg, max gas units = 0 Last survey at 772.4' MD / 766.08' TVD, 16.50° INC,
215.48° AZM, Distance from WP12 = 2.82', 2.62' low, 1.06' left Daily disposal to G&I = 228 bbls Total disposal to G&I = 228 bbls. Daily water hauled from L-Pad
Lake = 100 bbls Total water hauled from L-Pad Lake = 525 bbls. Daily fluid loss = 0 bbls Total fluid loss = 0 bbls. Daily metal recovered = 0 lbs Total metal
recovered = 0 lbs.
5/3/2022 Drill 12-1/4" surface hole from 906' to 1383' (1307' TVD). Drilled 477' = 79.5'/hr AROP. 502 GPM = 1910 psi, 60 RPM = 5-8K ft/lbs torque, WOB = 10-15-10K. MW
= 9.3 ppg, Vis = 192, ECD = 10.4 ppg, max gas units = 0. PU = 92K, SO = 88K, ROT = 89K Take GWD surveys until first good MWD survey at 1,044' and release
Gyro. Continue to build and turn 4 deg/100'. Drill 12-1/4" surface hole from 1383' to 2,146' (1,895' TVD). Drilled 763' = 127.2'/hr AROP. 500 GPM = 1,900 psi, 80
RPM = 5-7K ft/lbs torque, WOB = 5K. MW = 9.5+ ppg, Vis = 145, ECD = 10.6 ppg, max gas units = 0. PU = 110K, SO = 92K, ROT = 98K Continue to build and
turn 4° /100' to 1633', hold 41° tangent to the base of the Permafrost then build 4° /100'. Base of the Permafrost was at 2,030' (1,806' TVD). Drill 12-1/4" surface
hole from 2,146' to 2,619' (2,227' TVD). Drilled 473' = 118.3'/hr AROP. 551 GPM = 2,130 psi, 80 RPM = 6-7K ft/lbs torque, WOB = 5K. MW = 9.4+ ppg, Vis = 162,
ECD = 10.7 ppg, max gas units = 6,998. PU = 112K, SO = 90K, ROT = 105K At 2,530' pump 20 bbl hi-vis sweep, back on time with 50% increase, trace of oil and
6,998 units of gas. Build 4° /100' to 2,377' then hold 48° tangent Service the top drive. Drill 12-1/4" surface hole from 2,619' to 2,717' (2,294' TVD). Drilled 98' =
65.3'/hr AROP. 549 GPM = 1,990 psi, 80 RPM = 5-8K ft/lbs torque, WOB = 5-10K. MW = 9.5 ppg, Vis = 101, ECD = 10.8 ppg, max gas units = 700. PU = 115K,
SO = 93K, ROT = 105K Drill 12-1/4" surface hole from 2,717 to 3,385' (2,742' TVD). Drilled 668' = 111.3'/hr AROP. 550 GPM = 2,010 psi, 80 RPM = 7-10K ft/lbs
torque, WOB = 2-10K. MW = 9.4 ppg, Vis = 152, ECD = 10.1 ppg, max gas units = 5141. PU = 135K, SO = 97K, ROT = 110K Last survey at 772.4' MD / 766.08'
TVD, 16.50° INC, 215.48° AZM, Distance from WP12 = 20.66', 13.39' low, 15.73' right Daily disposal to G&I = 1046 bbls Total disposal to G&I = 1274 bbls. Daily
water hauled from L-Pad Lake = 1075 bbls Total water hauled from L-Pad Lake = 1600 bbls. Daily fluid loss = 0 bbls Total fluid loss = 0 bbls. Daily metal
recovered = 0 lbs Total metal recovered = 0 lbs.
Well Name:
Field:
County/State:
MP I-30
Milne Point
Hilcorp Energy Company Composite Report
, Alaska
5/2/2022Spud Date:
5/4/2022 Drill 12-1/4" surface hole from 3,385' to 3,888' (3,072' TVD). Drilled 503' = 83.8'/hr AROP. 550 GPM = 2,030 psi, 80 RPM = 9-11K ft/lbs torque, WOB = 5-12K. MW
= 9.2 ppg, Vis = 127, ECD = 9.98 ppg, max gas units = 435. PU = 150K, SO = 100K, ROT = 117K Maintain 48° tangent. Pump 20 bbl hi vis sweep at 3,525' back
on time with 10% increase. Ugnu Coal 1 at 3,676'. Drill 12-1/4" surface hole from 3,888' to 4,528' (3,474' TVD). Drilled 640' = 106.7'/hr AROP. 550 GPM = 2,160
psi, 80 RPM = 10-13K ft/lbs torque, WOB = 10-15K. MW = 9.3 ppg, Vis = 107, ECD = 10.1 ppg, max gas units = 818. PU = 162K, SO = 100K, ROT = 125K Begin
planned 4°/100' build and turn at 3,903'. Pre-treat mud with additional 0.5% of Drill-N-Slide (2% total) and ConDet prior to Ugnu MB sand. Ugnu L-sands at 4,218'.
Ugnu M-sands at 4,522' Drill 12-1/4" surface hole from 4,528' to 4,774' (3,612' TVD). Drilled 246' = 54.7'/hr AROP. 550 GPM = 2,160 psi, 80 RPM = 10-12K ft/lbs
torque, WOB = 9-14K. MW = 9.3 ppg, Vis = 95, ECD = 10.0 ppg, max gas units = 1,409. PU = 167K, SO = 100K, ROT = 126K. At 4,765' shakers blinded off.
Slowed pumps to 500 GPM then to 485 GPM but could not keep mud from going over the shakers. PU, slowed pumps to 268 GPM, work the DP 30' and screen
down the shakers. Service the top drive Drill 12-1/4" surface hole from 4,774' to 4838' (3,645' TVD). Drilled 64' = 64'/hr AROP. 550 GPM = 2,200 psi, 80 RPM = 10-
14K ft/lbs torque, WOB = 9-14K. MW = 9.2+ ppg, Vis = 93, ECD = 9.9 ppg, max gas units = 1,148. PU = 168K, SO = 98K, ROT = 127K Drill 12-1/4" surface hole
from 4,838' to 5,098' (3,762' TVD). Drilled 260' = 43.3'/hr AROP. 550 GPM = 2,275 psi, 80 RPM = 12-17K ft/lbs torque, WOB = 7-12K. MW = 9.3 ppg, Vis = 219,
ECD = 10.2 ppg, max gas units = 655. PU = 170K, SO = 101K, ROT = 125K Last survey at 5,042.85' MD / 3,739.58' TVD, 64.35° INC, 336.13° AZM, Distance
from WP12 = 23.13', 2.62' high, 22.90' right. Schrader Bluff NA at 4,948'. Daily disposal to G&I = 1393 bbls Total disposal to G&I = 2667 bbls. Daily water hauled
from L-Pad Lake = 1340 bbls Total water hauled from L-Pad Lake = 2940 bbls. Daily fluid loss = 0 bbls Total fluid loss = 0 bbls. Daily metal recovered = 0 lbs
Total metal recovered = 0 lbs.
5/5/2022 Drill 12-1/4" surface hole from 5,098' to 5,400' (3,856' TVD). Drilled 302' = 50.3'/hr AROP. 550 GPM = 2,175 PSI, 80 RPM = 11-12K ft/lbs torque, WOB = 7-11K.
MW = 9.2 ppg, Vis = 60, ECD = 9.92 ppg, max gas units = 1,101'. PU = 172K, SO = 102K, ROT = 125K High vis sweep at 5,096' was not seen at shakers due to
thick mud returns. Schrader Bluff OA sand at 5,390' MD / 3,853' TVD. Drill 12-1/4" surface hole from 5,400' to 5,859' (3,935' TVD). Drilled 459' = 76.5'/hr AROP.
550 GPM = 2,340 PSI, 80 RPM = 13-14K ft/lbs torque, WOB = 7-11K. MW = 9.4 ppg, Vis = 70, ECD = 10.2 ppg, max gas units = 657. PU = 165K, SO = 95K, ROT
= 123K Fault A was logged at 5,510’ / 3,882’ TVD with 89’ DTN throw placed the wellbore back into the SB N sands. Drill 12-1/4" surface hole from 5,859' to 6,084'
(3,949' TVD). Drilled 225' = 45'/hr AROP. 550 GPM =1,860 PSI, 80 RPM = 10-15K ft/lbs torque, WOB = 7-11K. MW = 9.3 ppg, Vis = 58, ECD = 9.8 ppg, max gas
units = 3,066. PU = 165K, SO = 96K, ROT = 125K Continued down with 85° inclination until the SB OA was observed again at 5,922’ MD / 3,940’ TVD. Obtain final
survey. Monitor the well for flow - static. Pump out of hole from 6,084' to 5,954' but pulling heavy. BROOH from 5,954' to 5,381' (top of the SB OA sand at 5,390').
550 GPM =1,860 PSI, 80 RPM = 10-15K ft/lbs torque, max gas units = 3,066. PU = 165K, SO = 96K, ROT = 105K. Final survey at 6,030.47' MD / 3,946.15' TVD,
87.09° INC, 3.72° AZM, Distance from WP12 = 15.10', 12.01' low, 9.16' left Pump 22 bbl hi-vis sweep and circulate it out at 550 GPM = 1,760 psi while
rotating/reciprocating 80 RPM = 13K ft/lbs from 5,381’ – 5,318’. Sweep was not seen over the shakers. Blow down the top drive. TIH from 5,381' to 6,084' on
elevators. Monitor the well for flow - static BROOH from 6,084' to 5,379' pulling 5-10 minutes/stand slowing as needed to clean up slides/tight spots. 550 GPM
=1,800 PSI, 80 RPM = 10-16K ft/lbs torque, max gas units = 337. PU = 185K, SO = 100K, ROT = 130K Daily disposal to G&I = 1269 bbls Total disposal to G&I =
3936 bbls. Daily water hauled from L-Pad Lake = 1090 bbls Total water hauled from L-Pad Lake = 4030 bbls. Daily fluid loss = 0 bbls Total fluid loss = 0 bbls.
Daily metal recovered = 0 lbs Total metal recovered = 0 lbs.
5/6/2022 BROOH from 5,379' to 3,289' pulling 5-10 minutes/stand slowing as needed to clean up slides/tight spots. 550 GPM =1,680 PSI, 80 RPM = 13K ft/lbs torque, max
gas units = 431. PU = 155K, SO = 90K, ROT = 115K BROOH from 3,289' to 2,010' pulling 5-10 minutes/stand slowing as needed to clean up slides/tight spots.
550 GPM =1,440 PSI, 80 RPM = 5-12K ft/lbs torque, max gas units = 283. PU = 120K, SO = 80K, ROT = 95K. Raised YP to 23 at 2,600'. Pulled slow from 2429' to
2334' to CBU prior to permafrost. BROOH from 2,010' to 718' pulling 5-10 minutes/stand slowing as needed to clean up slides/tight spots. 550 GPM =1,440 PSI, 80
RPM = 5-12K ft/lbs torque, max gas units = 283. PU = 85K, SO = 73K, ROT = 80K Observe the well for flow - static. TOOH standing back 5" HWDP from 718' to
533' (PU = 80K) with no swabbing. Blow down the top drive. Continue to TOOH standing back 5" HWDP from 533' to 162'. Lay down bottle neck crossover and
two 8" flex collars from 162' to 98'. Lay down bottle neck crossover and two 8" flex collars from 162' to 98'. Download MWD tools. Recovered 100% of the data. Lay
down BHA 98' to surface. Bit grade: PDC cutters_ 2-2-BF-C-X-1-WT-TD & cones_1-1-WT-A-F-1-NO-TD. Substantial wear predominantly from back reaming
incurred on the 10-5/8" ILS on the EWR M5 and the 12" 4-Rib Bottom Stabilizer on the 8" PDM. The 4 ribs of the 10-5/8" ILS 7/8 gone, and approximately 1/3 of 3
out of 4 ribs of the 12" 4-Rib Bottom Stabilizer on the 8" PDM worn away. Clean and clear the rig floor Service the top drive and rig floor equipment. Mobilize to the
rig floor and RU Volant CRT, power tongs and casing running equipment. PJSM for running 9-5/8" casing. Daily disposal to G&I = 959 bbls Total disposal to G&I =
4,895 bbls. Daily water hauled from L-Pad Lake = 1,060 bbls Total water hauled from L-Pad Lake = 5,090 bbls. Daily fluid loss = 15 bbls Total fluid loss = 15 bbls.
Daily metal recovered = 0 lbs Total metal recovered = 0 lbs.
5/7/2022 P/U and M/U 9-5/8" shoe track using ForumLok on each connection. Round nose float shoe joint, spacer joint, float collar joint. Fill shoe track and install the top hat.
M/U baffle adapter joint to 163'. Pump through shoe track at 3.5 BPM to ensure float equipment operating correctly - good. Torque to 21,000 ft/lbs with the Volant
tool. Fill casing on the fly and top off every 10 joints. Centralizers installed as per tally. 3 BPH losses. Run 9-5/8", 40# casing from 163' to 2,427' at 30'/min running
speed. 107K PUW / 83K SOW. Torque to 21,000 ft/lbs with the Volant tool. Fill casing on the fly and top off every 10 joints. Centralizers installed as per tally. 3 BPH
losses. Stage up pumps to 6 BPM, 135 PSI, reciprocate pipe 30'. Circulate a bottoms up beneath the permafrost and after the build and turn. 10 bbls lost while
circulating. Run 9-5/8", 40# casing from 2,427' to 3,874' at 30'/min running speed. PU = 155K & SO = 102K. Torque to 21,000 ft/lbs with the Volant tool. Fill casing
on the fly and top off every 10 joints. Centralizers installed as per tally. Install ES cementer with pup joints after joint #96 to 3,912'. Run 9-5/8", 47# casing from
3,912' to 6,078' at 30'/min running speed. PU = 275K & SO = 120K. Torque to 24,000 ft/lbs with the Volant tool. Fill casing on the fly and top off every 10 joints.
Centralizers installed as per tally. A total of 63 bbls was lost while running casing. Circulate and condition the mud for the cement job 6 BPM = 200 psi, 5 RPM =
20K ft-lbs torque and reciprocated 30'. Shut down the pumps, break out the Volant tool and re-dope the cup. Blow down the top drive. MU the Volant tool to the top
drive. RU the cement line to the Volant. Blow air down to the cement unit. Close upper and lower IBOP. Bring the pumps up to 6 BPM. PSJM for 1st stage cement
job. Continue to circulate at 6 BPM while rotating and reciprocating. HES filled lines with 5 bbls of fresh water. PT lines 1,000/4,000 psi (good test). Pump 1st stage
cement job: Mix & pump 60 bbls of 10 ppg tuned spacer with 4# red dye & 5# Pol-E-Flake in 1st 10 bbls, 3 BPM = 218 PSI. Drop bypass plug. Mix and pump 180
bbls of 211 bbls of 12.0 ppg lead cement (Type I/II cement) at 3 BMP = 210 psi Daily disposal to G&I = 317 bbls Total disposal to G&I = 5,212 bbls. Daily water
hauled from L-Pad Lake = 330 bbls Total water hauled from L-Pad Lake = 5,420 bbls. Daily fluid loss = 81 bbls Total fluid loss = 96 bbls. Daily metal recovered =
0 lbs Total metal recovered = 0 lbs.
hole from 5,859' to 6,084'
Run 9-5/8", 47# casing from
3,912' to 6,078' a
5/8/2022 Continue pumping 211 bbls total of 1st stage 12.0 ppg Type I/II lead cement (2.327 ft^3/sk yield, 504 sks total) @ 3.4 BPM, 215 PSI. Mix & pump 82 bbls 15.8 ppg
Premium G tail cement (1.156 ft^3/sk yield, 400 sks total) @ 3.45 BPM, 435 PSI. Rotate 3 RPM, 20K TQ & reciprocate 30'. Drop shutoff plug. Attempted to
reciprocate string after dropping plug, pulled 375K w/o movement. Parked string on depth. HES pumped 20 bbls fresh water at 5.7 BPM, 390 PSI. Displace with
255.6 bbls (2532 strokes) 9.5 ppg spud mud from rig at 6 BPM, 290 PSI. Began observing 10-30% losses. Slow to 5 BPM. Displace with 80 bbls 9.4 ppg Tuned
Spacer form Halliburton at 5 BPM, 365 PSI ICP / 545 PSI FCP. Observing 30-50% losses, slow to 4 BPM.
Began working string from 100K to 375K to help establish better returns. Returns did not improve, but regained movement of pipe. 245K PU / 105K SO. Displace
with 89.6 bbls (887 strokes) 9.5 ppg spud mud from rig at 4 BPM, 560 PSI ICP / 610 PSI FCP. Bumped plug 0.3 bbls early. CIP at 08:14 hours. Pressure up to
1150 PSI, hold for 3 min. Bleed off and check floats - good. Pressure up and observe ES cementer shift open at 1990 PSI (53 strokes). 269 bbls lost during entire
cement job. Pump through ES cementer at 2,180' at 6 BPM, 1380 PSI ICP / 570 PSI FCP. Began dumping to the rock washer when Pol-E-Flake was observed.
Dumped 99.6 bbls of spacer & interface. 35 bbls of cement observed back to surface. Take returns back to the pits & continue to circulate a total of 3x bottoms up.
Disconnect knife valve from accumulator. Drain stack and flush with black water. Re-connect knife valve to the accumulator. Continue to circulate through the ES
cementer at 2,180' at 6 BPM, 600 PSI for a total of 5x bottoms up. Circulate through ES cementer at 2,180' while preparing for 2nd stage cement job and waiting on
cement crew to bed rest & finish cement job on the Innovation rig. Pump 2 BPM = 80 PSI for 40 min then 6 BPM = 480 PSI for 20 min to minimize washout.
Condition mud, add 10 BPH water & 4 sacks/hr of Desco. Circulate through ES cementer at 2,180' while preparing for 2nd stage cement job and waiting on cement
crew to bed rest & finish cement job on the Innovation rig. Pump 2 BPM = 75 PSI for 40 min then 6 BPM = 475 PSI for 20 min to minimize washout. Circulate
through ES cementer at 2,180' while preparing for 2nd stage cement job and waiting on cement crew to finish cement job on the Innovation rig. Pump 2 BPM = 70
PSI for 40 min then 6 BPM = 430 PSI for 20 min to minimize washout. Cementers on location. Break out the Volant CRT, clean, inspect, re-dope and reengage.
Continue to circulate while warming up cement equipment. Daily disposal to G&I = 512 bbls Total disposal to G&I = 5,724 bbls. Daily water hauled from L-Pad Lake
= 260 bbls Total water hauled from L-Pad Lake = 5,680 bbls. Daily fluid loss = 269 bbls Total fluid loss =365 bbls. Daily metal recovered = 0 lbs Total metal
recovered = 0 lbs.
5/9/2022 Circulate through ES cementer at 2,180' while cementers warm up equipment. Pump 2 BPM = 70 PSI for 40 min then 6 BPM = 430 PSI for 20 min to minimize
washout. PJSM for cement job. 4624 bbls total circulated between cement jobs. AOGCC notified of upcoming BOP test at 06:08. Pump 5 bbls fresh water. P/T lines
to 1000 PSI / 4000 PSI - good. Mix & pump 60 bbls 10.0 ppg Tuned Spacer w/ 4# red dye & 5# Pol-E-Flake in 1st 10 bbls at 2.75 BPM, 110 PSI. Mix & pump 365
bbl 10.7 ppg ArcticCem lead cement (711 sxs at 2.883 ft^3/sk yield) at 3.7 BPM, 225 PSI ICP / 355 PSI FCP. Mix & pump 56 bbls 15.8 ppg Premium G tail cement
(270 sxs @ 1.17 ft^3/sk yield) at 2.9 BPM, 260 PSI. Drop closing plug. Pump 20 bbls 8.34 ppg fresh water at 6.25 BPM, 430 PSI. Displace with 9.4 ppg spud mud
at 6 BPM, 390 PSI ICP / 820 PSI FCP. Slow to 3 BPM, 520 PSI for last 10 bbls. Bump plug 1.0 bbl late. CIP at 10:35. 113 bbls of interface and 178 bbls of good
10.7 ppg cement returned. 100% returns during job. Pressure up and observe ES cementer shift close at 1760 PSI. Hold for 5 min - good. Bleed off and check
floats - good. Drain cement from stack. Disconnect accumulator line from knife valve. Flush diverter with black water 3x times. Jet flow line with black water. Vacuum
mud out of landing joint. Power down accumulator & disconnect lines from diverter. Remove turnbuckles. Back out grub screws and hoist stack. PU 140K indicated
on casing string. Wellhead rep install casing slips then set casing with 100K on slips. Cut casing as per wellhead rep. LD 17.78' cut joint. RD Volant Casing
Running Tool. ND riser. Dress the cut casing stub. Set diverter stack back down and ND diverter tee. Remove the diverter tee from the cellar. AOGCC inspector
Guy Cook waived witness of BOP testing at 17:06. Mobilize the slip lock tubing head and spacer spool into the cellar. NU the slip lock tubing head. PT the void to
500 psi for 5 minutes and 3,800 psi for 10 minutes (good test). Simops: Clear the rig floor of casing running equipment. Remove 13-5/8" x 11" crossover spool from
the bottom of the BOP stack and NU on the wellhead. NU 13-5/8" spacer spool and BOP stack. Install MPD riser. Install the test plug. Obtain RKB's. Change UPR
from 4-1/2" x 7" VBR's to 2-7/8" x 5" VBR's. RU BOPE testing equipment. Daily disposal to G&I = 1571 bbls Total disposal to G&I = 7,295 bbls. Daily water hauled
from L-Pad Lake = 330 bbls Total water hauled from L-Pad Lake = 6,010 bbls. Daily fluid loss = 0 bbls Total fluid loss =365 bbls. Daily metal recovered = 0 lbs
Total metal recovered = 0 lbs.
5/10/2022 Finish rigging up BOP test equipment. Fill stack and lines with fresh water. Close annular on 3.5" test joint and obtain good shell test to 250 PSI low / 3000 PSI
high. Install 1502 flange on OA and install 30' mousehole. 4-way valve on accumulator for annular leaking back to hydraulic tank. Changeout 4-way valve. Railroad
union disconnected during replacement damaged. Source new railroad union from the Innovation rig and install. Function test 4-way valve: working correctly with no
leaks. Conduct initial BOPE test to 250/3,000 psi: LPR (2-7/8” x 5” VBR’s) 3-1/2” & 5” test joints, UPR (2-7/8” x 5” VBR’s) with 3-1/2” & 5” test joints, annular with 3-
1/2” test joint, accumulator drawdown test and test gas alarms. All tests performed with fresh water against test plug. The states right to witness was waived by
AOGCC inspector Guy Cook via email on 5/09/22 at 17:06 hours. Tests: 1) Annular on 3.5" test joint, choke valves 1, 12, 13, 14, kill Demco & 5" FOSV. 2) Upper 2-
7/8" x 5" VBR on 3.5" test joint, choke valves 9, 11, kill HCR & 5" dart valve. 3) Lower 2-7/8" x 5" VBR on 3.5" test joints 4) Upper 2-7/8" x 5" VBR on 5" test joint,
choke valves 5, 8, 10, kill manual, upper IBOP. 5) Choke valves 4, 6, 7, lower IBOP. 6) Choke valve 2. 7) Choke HCR. 8) Choke manual. 9) Lower 2-7/8" x 5" VBR
on 5" test joint. 10) Blind rams & choke valve 3. 11) Manual choke. 12) Super choke Accumulator Test: System pressure = 3000 psi. Pressure after closure = 1600
psi. 200 psi attained in 45 seconds. Full pressure attained in 199 seconds. Nitrogen Bottles - 6 at 2000 psi RD BOPE testing equipment. Blow down the choke
manifold, kill lines and top drive. Pull the test plug and lay down the test joint. MU running tool and install the wear ring (ID = 9-1/4") RU 5" handling equipment.
PJSM. MU 8-1/2" cleanout assembly (BHA #2): Smith XR+CPS Tri-cone bit, 6-3/4" StrataForce 6/7-6 stage motor TIH with 8-1/2" cleanout assembly with HWDP
and jars from 31' to 588' Continue to TIH with 8-1/2" cleanout assembly with 5" DP from 588' to 2,110', PU = 92K & SO = 68K. MU the top drive and wash down to
tag with 12K at 2,175' at 125 GPM = 170 psi. Drill cement at 460 GPM = 760 psi, 40 RPM = 8K ft-lbs torque, WOB = 2-5K. Drill ES cement from 2,178' to 2,181'
(on depth). Continue to wash and ream from 2,181' to 2,202'. PU and ream through the ES cementer two times. Slack off through clean. Wash and ream from
2,202' to 2,489' at 450 GPM = 710 psi, 40 RPM = 7K ft-lbs torque, WOB = 3-5K getting cement over the shakers. TIH on elevators clean from 2,489' to 2,680'.
Blow down the top drive. TIH with 8-1/2" cleanout assembly from 2,680' to 5,919'.
Observing 30-50% losses, slow to 4 BPM.
Began working string from 100K to 375K to help establish better returns. Returns did not improve, but regained movement of pipe. 245K PU / 105K SO. Displace
with 89.6 bbls (887 strokes) 9.5 ppg spud mud from rig at 4 BPM, 560 PSI ICP / 610 PSI FCP. Bumped plug 0.3 bbls early.
f Desco. C
Bump plug 1.0 bbl
Mix & pump 82 bbls 15.8 ppg
Premium G tail cement (
Mix & pump 60 bbls 10.0 ppg Tuned Spacer w/ 4# red dye & 5# Pol-E-Flake in 1st 10 bbls at 2.75 BPM, 110 PSI. Mix & pump 365
bbl 10.7 ppg ArcticCem lead cement
211 bbls total of 1st stage 12.0 ppg Type I/II lead cement
5/11/2022 Wash down from 5,919' with 130 GPM, 330 PSI and tagged cement with 10K at 5,935'. Rack back stand and CBU at 450 GPM, 1160 PSI, 40 RPM, 17K TQ. R/U
test equipment and purge lines. Close upper 2-7/8" x 5" VBR on 5" drill pipe. Test 9-5/8" casing to 2600 PSI and hold for 30 min. - good test.
R/D test equipment and blow down lines. Drill cement and 9-5/8" shoe track from 5,935'. Equipment on depth: Baffle adapter @ 5,949', float collar @ 5,990' and
shoe 6,072' to 6,074'. Clean out rat hole to 6,084'. Ream baffle adapter, float collar and shoe 2x and trip through without difficulty. Drill 20' of new 8-1/2" hole from
6,084' to 6,104', 450 GPM, 1150 PSI, 40 RPM, 15-16K TQ, 5K WOB. 215K PU / 80K SO. 20' drilled in 0.14 hour = 143'/hr ROP. Circulate and condition mud for
FIT at 450 GPM, 1050 PSI, 40 RPM, 16K TQ. Reciprocate pipe from 6,070' to 6,014'. Good 9.4 ppg MW in and out. Rack back stand to 6,014'. Perform flow check,
slight static losses. Rig up test equipment. Close upper 2-7/8" x 5" VBR on 5" drill pipe. Purge choke & kill lines & choke manifold. Perform FIT to 12.0 ppg @
6,074' MD / 3,947' TVD with 9.4 ppg MW & 534 PSI applied at surface. Pumped 1.9 bbls & bled back 1.0 bbls. R/D test equipment & B/D lines. Pull one stand from
6,014' to 5,919' watching hole, fluid level dropping not swabbing. Pump 25 bbl 10.3 ppg dry job and blow down top drive. POOH on elevators from 5919' to 588'.
L/D 15 jts HWDP to shed. Rack back std w/ Jars, L/D Motor & Bit. Bit Grade = 1-1-WT-A-E-1-NO-BHA. 14 bbls loss while TOOH Clear & clean rig floor. Change out
master bushings to split bushings. Mobilize BHA and MPD equipment to rig floor. Monitor well on TT - Static M/U 8-1/2" NOV TK66 bit, NRP-A2 bit sleeve, 7600
Geo-Pilot, MWD ADR, DGR, PWD, directional tools, stabilizer and float sub to 92'. Plug in and initialize MWD tools. SimOps: Test MPD lines t/ 1250 psi -
Good.TIH 2 NM flex collars, float sub, HWDP & jars to 281'. TIH with 5" drill pipe stands f/ 281' t/ 2280'. Fill pipe & break-in RSS seals and test MWD. Continue
RIH with stands f/ Derrick to 5993’. Fill pipe every 20 stands. PUW 215k, SOW 75k. Calculated Displacement Returned. PJSM. Remove trip nipple and install MPD
RCD. Single in hole t/ 6065'. Break circulation @ 3 BPM - 350 psi , wash down & tag bottom on depth @ 6104'. Pull back into 9-5/8" shoe and prep for
displacement. Daily disposal to G&I = 260 bbls Total disposal to G&I = 7669 bbls. Daily water hauled from 6 Mile Lake = 330 bbls Total water hauled from 6 Mile
Lake = 6560 bbls. Daily fluid loss = 21 bbls Total fluid loss = 386 bbls. Daily metal recovered = 0 lbs Total metal recovered = 0 lbs.
5/12/2022 PJSM for displacement. Overboard mud to the rock washer then pump high viscosity spacer. Displace wellbore with 8.9 ppg BaraDrill-N Close MPD chokes and
monitor pressure - no build. L/D two joints of 5" drill pipe to 6,056'. Slip and cut 80' of drilling line, calibrate block height, adjust draw works brakes, service top drive,
inspect saver sub and grabber dies - good. Sim-ops: Clean pit #4 and surface equipment and load pit #4 with mud. Monitor pressure with MPD choke closed -
static. Blow down MPD. Fill MPD lines. Slow pump rates. Wash to bottom f/ 6,056' t/ 6,104' with 125 GPM, 220 PSI. Drill 8-1/2" lateral from 6,104' to 6,657', 553'
drilled, 100.55'/hr AROP. 500 GPM, 1275 PSI, 120 RPM, 14-15K TQ, 5-12K WOB, 170K PU / 70K SO / 114K ROT. 9.1 MW, 40 vis, 9.88 ECD, 699u max gas.
MPD choke open while drilling, closed on connections with no pressure build. 10 bbls of 5% BaraLube W-1032 leaked into the active mud system @ 6450'.
Pumped 28 bbls pill with 5% BaraLube W-1032 at 6500'. Once dispersed in the system = 0.25%. 190K PU / 75K SO prior and 170K PU / 70K SO after addition.
Drill 8-1/2" lateral from 6,657' to 7,325', 668' drilled, 111.33'/hr AROP. 500 GPM, 1460 PSI, 120 RPM, 14-18K TQ, 5-12K WOB, 190K PU / 75K SO / 113K ROT.
9.2 MW, 43 vis, 10.52 ECD, 840u max gas. MPD choke open while drilling, closed on connections with no pressure build. Pump 25 bbl hi-vis sweep @ 7001’.
Return on time w/ 20% increase Exit bottom of OA-3 @ 7290’ in anticipation of Fault #1. Crossed Fault #1 at 7,335’ MD. 38' throw DTN, moved the bit from below
OA-3 to above OA-1. Re-enter top of OA-1 at 7,340’ MD. Total of 50’ drilled outside the OA package Drill 8-1/2" lateral from 7,325' to 7,894', 569' drilled, 94.83'/hr
AROP. 500 GPM, 1550 PSI, 120 RPM, 18K TQ, 5-13K WOB, 230K PU / 60K SO / 115K ROT. 9.2 MW, 43 vis, 10.5 ECD, 2644u max gas. MPD choke open while
drilling, closed on connections with no pressure build. Last survey at 7824.00’ MD / 3966.77' TVD, 92.96° inc, 6.52° azm, 3.82’ from plan, 3.25' low and 2.01’ left.
We have drilled 9 concretions for a total thickness of 24' (1.4% of the lateral). Daily disposal to G&I = 865 bbls Total disposal to G&I = 8534 bbls. Daily water
hauled from 6 Mile Lake = 330 bbls Total water hauled from 6 Mile Lake = 6890 bbls. Daily fluid loss = 0 bbls Total fluid loss = 386 bbls. Daily metal recovered = 0
lbs Total metal recovered = 0 lbs.
5/13/2022 Drill 8-1/2" lateral from 7,894' to 8,372' MD / 3.931' TVD, 478' drilled, 79.67'/hr AROP. 500 GPM, 1640 PSI, 120 RPM, 19K TQ, 5-13K WOB, 220K PU / 65K SO /
115K ROT. 9.2 MW, 43 vis, 10.5 ECD, max gas 2520u. High vis sweep at 7,989' was 500 strokes early with 10% increase. MPD began holding 200 PSI on
connections at 8,274' to maintain constant BHP (10.2 EMW), chokes full open while drilling. Pump 27 bbl 5% BaraLube W-1032 pill at 8,290'. PU reduced from
220K to 210K and torque from 19K to 16K. Encountered Fault #2 at 7,997’ with ~15 DTN throw placing the wellbore in OA-2.
Crossed Fault #3 at 8,180’ with 13’ DTN throw placing the wellbore above the OA sands. Steer down at 87° and re-aquire OA sands at 8,333’. Drill 8-1/2" lateral
from 8,372' to 9036' / 3961' TVD. 664' drilled, 110.66'/hr AROP. 500 GPM, 1675 PSI, 100-120 RPM, 18-20K TQ, 8-13K WOB, 225K PU / 65K SO / 110K ROT.
9.2 MW, 42 vis, 10.81 ECD, max gas 1335u. Gassed up mud running over shakers, began holding 120 PSI drilling and 360 PSI on connections at 8,722' for 11.0
EMW. Gas dropped from 1193u to 476u. Began adding 0.25% for 0.5% total BaraLube W-1032 at 8,734'. Crossed Fault #4 at 8485’ with 17’ DTN throw moving
wellbore from the OA-1 to OA-3. Drill 8-1/2" lateral from 9036’ to 9641', 605' drilled, 100.83'/hr AROP. 500 GPM, 1695 PSI, 120 RPM, 18-20K TQ, 5-15K WOB,
225K PU / 60K SO / 110K ROT. 9.15 MW, 42 vis, 10.67 ECD, 887u max gas. MPD holding 80 psi drilling, Trapping 340 psi on conn to maintain constant BHP
(10.8 EMW) Maintain trajectory through the OA-3. Pump 30 bbls Hi-Vis sweep @ 9040’ on-time 15% increase. Begin adding 0.5% Baralube W-1032 @ 9500’ for a
1% target. Drill 8-1/2" lateral from 9641’ to 10369' / 3092', 728' drilled, 121.33'/hr AROP. 500 GPM, 1720 PSI, 120 RPM, 17K TQ, 5-12K WOB, 165K PU / 75K SO
/ 110K ROT. 9.0 MW, 45 vis, 10.80 ECD, 1028u max gas. MPD full open with 50 psi line restr while drlg, Trapping 360 psi on conn PUW reduced from 225k to
160k, SOW increase 10k to 70k and Tq down 4k from 20k to 16k with W-1032 at 1%. Pump 30 bbls Hi-Vis sweep @ 9989’. Return on time with 10% increase.
Start undulate up @ 9690', enter OA-1 @ 10013' MD. Last survey at 10204.40’ MD / 3986.03' TVD, 88.26° inc, 4.49° azm, 48.79’ from plan, 35.50' low and 33.48’
left. We have drilled 25 concretions for a total thickness of 93' (2.3% of the lateral). Daily disposal to G&I = 1388 bbls Total disposal to G&I = 9922 bbls. Daily water
hauled from 6 Mile Lake = 1210 bbls Total water hauled from 6 Mile Lake = 8100 bbls. Daily fluid loss = 0 bbls Total fluid loss = 386 bbls. Daily metal recovered =
9.5 lbs Total metal recovered = 9.5 lbs.
5/14/2022 Drill 8-1/2" lateral from 10,369' to 11,036', 667' drilled, 111.17'/hr AROP. 500 GPM, 1850 PSI, 120 RPM, 19K TQ, 5-15K WOB, 175K PU / 60K SO / 115K ROT.
9.0 MW, 48 vis, 10.9 ECD, max gas 2023 units. MPD chokes open while drilling with 50 PSI line restriction, 320 PSI on connections. Entered OA-2 at 10,893' then
begin planned undulation down at 10,939'. Entered OA-3 at 11,149'. Drill 8-1/2" lateral from 11,036' to 11,867', 831' drilled, 138.5'/hr AROP. 500 GPM, 1910 PSI,
120 RPM, 20K TQ, 7-15K WOB, 180K PU / no SO / 110K ROT. 9.1 MW, 45 vix, 10.93 ECD, max gas 582 units. MPD chokes open while drilling with 50 PSI line
restriction, 340 PSI on connections. Closest point to J-22 was 74’ at 11,225’. High vis sweep at 11,321' back on time w/ no increase. Drill 8-1/2" lateral from 11,867’
to 12,466', 599' drilled, 99.83'/hr AROP. 500 GPM, 1910 PSI, 120 RPM, 20-23K TQ, 8-16K WOB, 220K PU / no SO / 108K ROT. 9.05 MW, 45 vis, 10.96 ECD,
583u max gas. MPD chokes open while drilling with 50 PSI line restriction, 340 PSI on connections. Closest point to J-09 was 223’ at 12,225’, & J-09A was 47’ @
12393’. High vis sweep at 12,007' back on time w/ 30%. Drill 8-1/2" lateral from 12,466’ to 12,844’ / 4,047 TVD, 378' drilled, 63'/hr AROP. 500 GPM, 1890 PSI, 120
RPM, 23K TQ, 5-15K WOB, 215K PU / no SO / 115K ROT. 9.0 MW, 48 vis, 10.9 ECD, 653u max gas. MPD chokes open while drilling with 50 PSI line restriction,
360 PSI on connections. Start undulating up with 91.5° @ 12621’ targeting the OA-1. Last survey at 12678.56’ MD / 4051.87' TVD, 89.99° inc, 15.25° azm, 21.49’
from plan, 18.32' High and 11.25’ right. We have drilled 46 concretions for a total thickness of 206' (3.1% of the lateral). Daily disposal to G&I = 1331 bbls Total
disposal to G&I = 11,253 bbls. Daily water hauled from 6 Mile Lake = 1580 bbls Total water hauled from 6 Mile Lake = 9680 bbls. Daily fluid loss = 0 bbls Total
fluid loss = 386 bbls. Daily metal recovered = 10 lbs Total metal recovered = 19.5 lbs.
Test 9-5/8" casing to 2600 PSI and hold for 30 min. - good test.
5/15/2022 Drill 8-1/2" lateral from 12,844' to 13,438' (4,051' TVD), 594' drilled, 99'/hr AROP. 500 GPM, 2000 PSI, 120 RPM, 24K TQ, 5-15K WOB. 220K PU / no SO / 115K
ROT. 9.0 MW, 45 vis, 11.2 ECD, 2005u max gas. High vis sweep at 13,034' on time with 10% increase. Performed planned undulation from OA-3 to OA-1, exit OA-
3 at 12,874’ and entered OA-1 at 13,022’. Drill 8-1/2" lateral from 13,438' to 14,134' (4,066' TVD), 696' drilled, 116'/hr AROP. 500 GPM, 1985 PSI, 120 RPM, 24-
26K TQ, 5-13K WOB. 240K PU / no SO / 110K ROT. 9.15 MW 45 vis, 11.45 ECD, 607u max gas. Begin increasing BaraLube W-1032 to 1.25% to help reduce
torque at 13805'. Pump high vis sweep at 13,986', on time with 10% increase. Drill 8-1/2" lateral from 14,134' to 14,462' (4,076' TVD), 328' drilled, 82'/hr AROP.
500 GPM, 2075 PSI, 120 RPM, 27K TQ, 5-15K WOB. 235K PU / no SO / 109K ROT. 9.15 MW 49 vis, 11.43 ECD, 430u max gas. MPD chokes open while drilling
with 50 PSI line restriction, 360 PSI on connections. ECD’s climb to 11.6 ppg and torque @ 28k with spikes to 30k. Experiencing intermittent string stalling. Pump
Tandem lo-vis / hi vis sweeps and circulate around for clean-up cycle while rot & ricip string 90’. 500 GPM - 2075 psi, 120 RPM - 28k Tq. ECDs reduced to 11.15
ppg, no improvement with Tq. Drill 8-1/2" lateral from 14,462’ to 15032' (4097' TVD), 570' drilled, 81.42'/hr AROP. 500 GPM, 2110 PSI, 120 RPM, 29K TQ, 5-15K
WOB. 240K PU / no SO / 112K ROT. 9.0 MW 46 vis, 11.30 ECD, 1028u max gas. 14,590’ Start raising Bara-lube Gold Seal to 3%. No Tq improvement observed
Continue geo-steer to maintain the OA-1. Started undulate down at 14692’ with 86°. Enter the OA-2 @ 14,822'. Adjusting parameters (WOB/ROP, RPM) as
needed to minimize string stalling. MPD chokes open while drilling with 46 PSI line restriction, 360 PSI on connections. Closest AC w/ MPJ-15 @ 14661' MD had a
minimum C-C distance of 93'. Last survey at 14962.98’ MD / 4091.45' TVD, 85.85° inc, 19.28° azm, 28.45’ from plan, 22.38 High and 17.57’ left. We have drilled
48 concretions for a total thickness of 215' (2.4% of the lateral). Daily disposal to G&I = 1269 bbls Total disposal to G&I = 12522 bbls. Daily water hauled from 6
Mile Lake = 1360 bbls Total water hauled from 6 Mile Lake = 11040 bbls. Daily fluid loss = 0 bbls Total fluid loss = 386 bbls. Daily metal recovered = 9 lbs Total
metal recovered = 28.5 lbs.
5/16/2022 Drill 8-1/2" lateral from 15,023' to 15,474' (4,122' TVD), 451' drilled, 75.17'/hr AROP. 500 GPM, 2040 PSI, 120 RPM, 29-31K TQ, 5-15K WOB, 275K PU / no SO /
110K ROT. 9.0 MW, 46 vis, 11.4 ECD, 1483u max gas. Pumped 6% lube pill (3% Gold Seal & 3% W-1032) at 15,223 - no reduction of torque. Rotary beginning to
stall at 30K torque limit and ROP slowed to 20' per hour on concretions / hard drilling. M-I 776 lube arrived on location at 11:00. Perform compatibility testing with W -
1032 lube and mud - no issues. Drilling in OA-3. Crossed Fault #5 @ 15,079' with 8' DTN throw into OA-2. Continue down and re-entered OA-3 at 15,308'. Drill 8-
1/2" lateral from 15474’ to 15983' (4136’ TVD), 509' drilled, 92.5'/hr AROP. 500 GPM, 2095 PSI, 120 RPM, 23K TQ, 5-15K WOB. 205K PU / no SO /110K ROT,
9.15 ppg MW, 43 vis, 11.21 ECD, max gas 1526u. MPD chokes full open drilling with 50 PSI, trap 360 PSI on connections Added 0.5% of M-I 776 lube. Torque
reduced from 30K to 28K on the first circulating and continue to fall as low as 22K. Undulate up and enter the OA-2 at 15,729' & OA-1 at 15,824'. PUW reduced
from 255K to 255K. Service rig - grease wash pipe. Obtain SPRs. Drill 8-1/2" lateral from 15983’ to TD @ 16500' (4133’ TVD), 517' drilled, 103.4'/hr AROP. 500
GPM, 2070 PSI, 120 RPM, 27K TQ, 5-15K WOB. 205K PU / no SO /109K ROT, 9.15 ppg MW, 46 vis, 11.54 ECD, max gas 796u. Hi-Vis Sweep at 16,079, on time
w/ 15% increase. Maintain OA-1 to TD. Final Survey at 16429.54’ MD / 4135.19' TVD, 91.60° inc, 12.14° azm, 16.51’ from plan, 16.11' high and 3.59’ right. We
have drilled 56 concretions for a total thickness of 283' (2.7% of the lateral). Pump 30 bbl hi-vis sweep. 500 GPM 2140 psi, 120 RPM 24k Tq. On time, 10%
increase . Rot & Recip 60’ while sweep in hole. Cont to circ an additional 5.5x BU pumping 450-500 gpm, 1750-2100 psi, 120 RPM, 22-24K tq. Rack stand back
ea. BU t/ 16142'. Losses @ 10 BPH - Reduce pump rate to 450 GPM Prep pits for pumping SAPP train and displacing to lubricated brine. Clean Pill Pit and Pits 4
& 5. Add 1.5% Bara-lube Gold Seal and 0.5% M-I 776 to trucks as they arrive on location, bring concentration of lube to 4.5% total, 0.5% being W-1032 that was
added when initial mix. Daily disposal to G&I = 694 bbls Total disposal to G&I = 13216 bbls. Daily water hauled from 6 Mile Lake = 1320 bbls Total water hauled
from 6 Mile Lake = 12360 bbls. Daily fluid loss = 117 bbls Total fluid loss = 503 bbls. Daily metal recovered = 4.5 lbs Total metal recovered = 33 lbs.
5/17/2022 Continue to circulate while preparing the mud pits for displacement to QuikDril-N. 450 GPM, 1800 PSI, 120 RPM, 24K TQ. 11.06 ECD. Reciprocate to 16,141'.
Ream to bottom at 16,500' then continue to circulate until mud pits ready. Circulated a total of 8 bottoms up. PJSM for displacement. No losses. Pump SAPP train:
35 bbls SAPP, 25 bbls QuikDril-N, 35 bbls SAPP, 25 bbls QuikDril-N, 35 bbls SAPP, 25 bbls QuikDrill-N, 250 GPM, 1030 PSI, 60 RPM, 21K TQ. Displace well
with 8.9 ppg QuikDril-N, 335 GPM, 1000 PSI, 60 RPM, 13K TQ. Reciprocate pipe 70' f/ 16,500' t/ 16,430'. No losses. 165K PU / 65K SO / 110K ROT Perform PST
on returns at flow line: 350mL through 250u screen 3x - 5.44, 5.76, 5.24 sec. Suction pit: 350mL through 250u screen 3x - 6.1, 6.39, 7.81 sec. Obtain new SPRs.
L/D double f/ 16,500' t/ 16,462' Monitor pressure with MPD with 9.1 ppg return fluid. Trap 60 PSI, dropped to 42 PSI over 11 min. Bleed off twice, stabilized at 19
PSI on gauge. 14 PSI observed with hydrostatic column - only 5 PSI. Wellbore static. BROOH F/ 16458' T/ 14358' at 5-10 mins a stand. MPD full open choke with
ECD 10.6-10.7 while BROOH & trapping 200 psi on connection. 500 GPM, 1500 PSI, 120 RPM, 13k TQ, Max Gas 74u. 165K PU, 65K SO, 115K ROT. Laying
down DP via 90' mousehole Saw an initial 24 BPH loss when reamed past fault at 15,079' then appeared to slow. Losses picked back up to 20 BPH, slow flow rate
to 450 GPM. BROOH F/ 14358' T/ 11705' at 5-10 mins a stand. MPD full open choke while BROOH & trap 200 psi on connection. 420 GPM, 1025 PSI, 120 RPM,
12k Tq, Max Gas 85u, ECD- 10.3. 165K PU, 80K SO, 115K ROT. Dynamic losses @ 15-20 BPH. Reduced flow to 420 GPM to aid in losses. Laying down DP via
90' mousehole BROOH F/ 11705' T/ 9324' at 5-10 mins a stand. MPD full open choke while BROOH & trapping 200 psi on connection. 420 GPM, 1050 PSI, 120
RPM, 10k Tq, Max Gas 83u, ECDs -10.23. 155K PU, 85K SO, 115K ROT. Dynamic losses @ 8-15 BPH. Laying down DP via 90' mousehole Daily disposal to G&I
= 2360 bbls Total disposal to G&I = 15576 bbls. Daily water hauled from 6 Mile Lake = 700 bbls Total water hauled from 6 Mile Lake = 13060 bbls. Daily fluid loss
= 224 bbls Total fluid loss = 727 bbls. Daily metal recovered = 4.5 lbs Total metal recovered = 37.5 lbs.
5/18/2022 BROOH from 9324' to 6849' 5-10 min/stand, slowing as needed. 420 GPM, 970 PSI, 120 RPM, 7k TQ, 10.6 ECD. MPD chokes open while reaming, trapping 200
PSI on connections. Observed slight pack off at 8227' & 8186'. slowed and cleared up - corresponds to fault #3 at 8180'. loss rate avg @ 12-13 BPH BROOH from
6849' to 5993' just above the 9 5/8'' shoe @ 6072' 5-10 min/stand, slowing as needed. 420 GPM, 910 PSI, 120 RPM, 6-7k TQ, 10.6 ECD. max gas 392u. MPD
chokes open while reaming, trapping 200 PSI on connections. Losses BR to shoe =277 bbls Build and pump 2-25 bbl hi vis sweeps at 5993', 425 gpm, 50 rpm,
55k torque working pipe 90', 1st sweep on time with 15% increase, 2nd sweep on time with 25% increase. Circulate hole clean. Perform passing PST at FL, 7.15 /
6.53 / 6.71 Monitor MPD pressure build in 5 min intervals 3 times. 21 psi, 19 psi, 16 psi. Blow down TD, Monitor well for flow at 2” on RCD. well is static, no flow.
Continue to monitor, PJSM- prep for removing RCD Remove RCD, install trip nipple, ensure no leaks, BD MPD line, drop drift on wire, pump dry job, BD TD. TOOH
from 5993' to BHA @ 281’. Rack all DP in Derrick. Loss rate @ ~8 BPH Flow check before pulling BHA, slight losses. L/D jar stand, float subs, NMFCs, Download
MWD data, L/D remaining BHA. 8 1/2'' PDC Bit grade= 2-1-BT-M-X-I-CT-TD. 39 bbl losses TOOH from shoe Clear rig floor of BHA accessories and tools. Clean
the rig floor in prep to run lower completion string. Monitor well, static loss rate @ 4 BPH Load tools, stop rings & centralizers to rig floor. R/U 4 1/2'' handling
equipment and power tongs. Remove split bushings. M/U XO to FOSV. Monitor well, static loss rate @ 4 BPH Run 4-1/2'', 13.5#, L-80 H625 drilled lower
completion as per tally to 1434'. Torque to optimum @ 9600 ft/lbs with Doyon double stack tongs. 52K PU / 56K SO. 2.3 bbls loss while RIH w/ liner. Daily disposal
to G&I = 304 bbls Total disposal to G&I = 15880 bbls. Daily water hauled from 6 Mile Lake = 450 bbls Total water hauled from 6 Mile Lake = 13510 bbls. Daily
fluid loss = 191 bbls Total fluid loss = 918 bbls. Daily metal recovered = 4.5 lbs Total metal recovered = 41lbs.
Drill 8-1/2" lateral from 15983’ to TD @ 16500' (
5/19/2022 Continue to run 4-1/2'', 13.5#, L-80 H625 drilled lower completion as per tally from 1434' to 2317'. Torque to optimum @ 9600 ft/lbs with Doyon double stack tongs.
62K PU / 62K SO. 2.3 bbl loss rate while RIH w/ liner Backup power tong closing ram anchor bolt failed, C/O with backup set of power tongs. Continue to run 4 1/2''
completion from 2317' to 5817' at joint 143, hydraulic pressure gauge on power tongs failed, releasing 1/2 gallon hyd fluid onto the rig floor. Torque to 9600 ft/lbs
with Doyon double stack tongs. 2.3-2.5 bph loss rate while RIH w/ liner. Cleanup hydraulic fluid from rig floor and on power tongs, replace gauge. Continue to run 4
1/2'' completion from 5817' to 10608', Note: Before exiting the 9 5/8'' shoe @ 6072' PU= 92k, SO= 80k, slow running speed to 30-40 fpm. Torque to 9600 ft/lbs
with Doyon double stack tongs. 2.5-3 bph loss rate while RIH w/ liner C/O to 5'' elevators. M/U Baker 7" x 9-5/8" SLZXP liner top packer assy as per BOT rep at
10530', verify 9 pins set @ 2396 psi shear, verify pipe count. Obtain parameters: 115K PU / 70K SO RIH with 1 stand 5'' DP t/ 10645’, Pump 10 bbls to ensure
clear flow path through Baker tools, 3 bpm, 120 psi. Cont RIH with 4-1/2'', 13.5#, L-80 H625 pre-drilled lower completion with total 46 stds 5'' DP out of derrick f/
10645’' to 15022' @ 30 fpm. Loss rate continues at 1-3 bph. PU 165K, SO 85K S/O wt stabilize @ 87k then trend down 3k over 2x stands. Start to run HWDP from
pipe shed. Drift & Single in with 46 jts 5” HWDP f/ 15022’ t/ 16442’ M/U a stand of 5” DP from Derrick. Circulate 3 BPM – 250 psi. RIH & tag bottom 2x w/ 10k wt.
200k P/U, 120k SO. Total of 67 bbls losses while running liner. Lay down top single. L/D single of DP. Drop 1” phenolic ball. Kelly up and set string on depth, in
tension with 180k PU. Pump ball down with 30 bbl hi-vis sweep. Ball on seat @ 773 stks - 400 psi. Pressure up t/ 2920 psi, observed shear @ 2520 psi. Hold
pressure for 3 min. Top Drive swivel packing start leaking. Bleed pressure down. Grease and attempt to tighten packing. Pressure back up and packing leaking at
1200 psi. P/U to 180k, not released. S/O t/ 50k and repeat. Not released. Break out TD and R/U FOSV & Head pin to string. Pressure up to 4000 psi with rig pump
then swap to test pump. Continue pressure up, shear ball seat @ 5100 psi. P/U and confirm release w/ 165k PUW, 140k SOW. LTP @ 5865.20' Set dn 10k and
rig up test equipment. Close annular, purge air from system, test LTP to 1500 psi for 10min charted - good test. bleed pressure off. 2.6 bbls pumped, 2.6 bbls
returned. Rig down test equipment. C/O TopDrive swivel packing.
5/20/2022 Finish C/O swivel packing, LD FOSV, pressure test swivel packing to 2000 psi against IBOP, good, bleed off pressure, MU TD and open IBOP. Submit 24 hr
notification to AOGCC for MIT, state rep Brian Bixby waived witness at 06:50 Pressure to 300 psi, unsting from LTP, PU 9' to 5856' seeing pressure dump continue
to PU 30' above TOL to 5835' pumping 8 bpm, 800 psi, CBU working pipe to 5810', sweep from pumping ball on seat back 200 stks late. BD TD. 4 bbl losses CBU.
PU 170K, SO 140K Rig electrician troubleshoot pipe skate ODS eject sensor not functioning, found damaged cable, replace and re-routed same, working correctly
POOH with LRT from 5835' L/D 5'' DP and HWDP, inspect and LD LRT, RIH with remaining 13 stands DP from derrick. 33.7 bbl losses LD DP RIH with remaining
13 stands DP from derrick. Cut and slip 93' drilling line. Service drawworks, Topdrive & roughneck. Daily disposal to G&I = 196 bbls Total disposal to G&I = 16076
bbls. Daily water hauled from 6 Mile Lake = 175 bbls Total water hauled from 6 Mile Lake = 13685 bbls. Daily fluid loss = 69 bbls Total fluid loss = 1063 bbls.
Daily metal recovered = 0 lbs Total metal recovered = 41 lbs.
RIH & tag bottom 2x w/ 10k wt.
LTP @ 5865.20'
Activity Date Ops Summary
5/20/2022 POOH f/ 1332' to surface, laying down all remaining 5" drillpipe. Total of 21 bbls loss round tripping 13 stands DP,Clean and clean rig floor. Mobilize Centrilift tools,
110 cannon clamps, tech line spool and 3-1/2” handling equipment to rig floor. R/U to run upper completion. M/U XO’s to FOSV. Pull wear bushing. Static losses @
3.5 BPH,P/U bullet seal assembly and proceed to RIH picking up 3-1/2” 9.3# L-80 EUE tubing to 768’ MD. Torque to 2800 ft/lbs with Doyon double stack
tongs.,M/U XN nipple assembly, 1 joint tubing & Baker gauge carrier. M/U the Tec wire to the gauge. Test gauge (good).,Continue to RIH with 3-1/2” 9.3# L-80
EUE upper completion from 841' to 3031' spooling Tec wire and installing cannon clamps the first 10 joints then every other joint. Torque to 2800 ft/lbs with Doyon
double stack tongs. Test Tec wire every 1,000'. Losses @ 3 BPH.Daily disposal to G&I = 196 bbls; Total disposal to G&I = 16076 bbls. Daily water hauled from 6
Mile Lake = 175 bbls; Total water hauled from 6 Mile Lake = 13685 bbls. Daily fluid loss = 69 bbls; Total fluid loss = 1063 bbls. Daily metal recovered = 0 lbs; Total
metal recovered = 41 lbs.
5/21/2022 Continue to RIH with 3-1/2” 9.3# L-80 EUE upper completion from 3031' to 5820' @ jt 184 spooling Tec wire and installing cannon clamp every other joint. Torque
to 2800 ft/lbs with Doyon double stack tongs. Test Tec wire every 1,000'. Losses @ 3 BPH,MU joint 185 and 186, locate and NOGO out seal assy @ 5880', close
bag, reduce annular to 550 psi, apply 300 psi on IA, strip out until ports exposed and pressure dumped, open bag, LD jts 186, 185 and breakout jt 184,Space out as
per Baker rep, MU 3-3 1/2'' Pup jts, 10.22', 7.82' and 4.10'= 22.14', MU jt 184, XO pup and tubing hanger with XO and landing joint, terminate and test tech wire,
pull the bushings, drain stack, SO to 5877'. PU 77K, SO 65K,RU to reverse, MU headpin, swing, low torque valve and hose, fill the hole, close the bag, apply 300
psi on IA, strip out exposing the ports, PJSM for reversing in CIB and diesel freeze protect.,With rig pump #1 pump 185 bbls 8.5 ppg 2% KCL CIB down the IA 7
bpm, 1350 psi followed with 186 bbls diesel off vac truck at 4 bpm, 650 psi freeze protecting the IA to 3000', S/O closing the ports, open annular, drain stack to
cellar, blow down choke and kill line. Land out hanger with 25k on hanger, EOP @ 5878.89' @ 1.70' off the NOGO. WHR RILDS.,Rig up test equipment and lines
to annulus. With the rig pump, MIT 9.625" X 3.5" IA to 2,500 PSI for 30 min, good. Pump 5.0 bbls, bled 4.8 bbls. AOGCC rep Brian Bixby waived witness for MIT at
06:50, 5/20/22. Back out landing joint. P/U Tee Bar and set BPV as per WellHead Reps. Rig on Gen power @ 18:45, Remove the MPD drip pan and bell nipple.
Remove the kill line hose off the mud cross N/D BOP stack, remove adapter spool and set the BOP stack on the pedestal. SimOps: Clear & Clean rig floor. L/D
mouse holes. Cleaning mud pits. Remove koomey lines from BOP's in prep to remove Stack. Clean out cellar box.,Install CTS plug in BPV. Mobilize tree into cellar
and set on Wellhead. Terminate tec wire at adapter flange. Torque adapter flange bolts. PT the tubing hanger void to 500 psi for 5 minutes and 5,000 psi for 10
minutes (good test). SimOps: Continue cleaning pits. Secure pipe shed for rig move. RU to test the tree. Fill the tree with diesel. PT the tree to 250/5,000 psi (good
test). RD testing equipment.,Daily disposal to G&I = 436 bbls; Total disposal to G&I = 16512 bbls. Daily water hauled from 6 Mile Lake = 50 bbls; Total water
hauled from 6 Mile Lake = 13735 bbls. Daily fluid loss = 40 bbls; Total fluid loss = 1103 bbls. Daily metal recovered = 0 lbs; Total metal recovered = 41 lbs.
5/22/2022 Centrilift final readings: tubing pressure = 1676 psi, IA pressure = 1679 psi, tubing/IA temp = 74°F. Pull the CTS plug and BPV with the dry rod. R/U to pump down
the tubing. PT the lines to 3,000 psi (good test). Pump 26 bbls diesel freeze protect down tubing @ 2 BPM, initial 240 PSI, final 440 psi, shut in and secure the
tree.,Flush lines with water, blow down and rig down lines, finish cleaning the pits. Install gauges on tree, tubing 200 psi, IA 0 psi. Welder cap mousehole in the
cellar box. Release rig at 10:00.
Well Name:
Field:
County/State:
MP I-30
Milne Point
Hilcorp Energy Company Composite Report
, Alaska
5/2/2022Spud Date:
PT the tubing hanger void to 500 psi for 5 minutes and 5,000 psi for 10
minutes (good test).
MIT 9.625" X 3.5" IA to 2,500 PSI for 30 min, good.
TD Shoe Depth: PBTD:
No. Jts. Returned
RKB RKB to BHF RKB to THF
Jts.
1
1
1
1
1
92
1
1
1
51
1
X Yes No X Yes No 347.1
Fluid Description:
Liner hanger Info (Make/Model): Liner top Packer?: Yes No
Liner hanger test pressure:X Yes No
Centralizer Placement:
Preflush (Spacer)
Type: Density (ppg) Volume pumped (BBLs)
Lead Slurry
Type:Sacks: Yield:
Density (ppg) Volume pumped (BBLs) Mixing / Pumping Rate (bpm):
Tail Slurry
Type:Sacks: Yield:
Density (ppg) Volume pumped (BBLs) Mixing / Pumping Rate (bpm):
Post Flush (Spacer)
Type: Density (ppg) Rate (bpm): Volume:
Displacement:
Type: Density (ppg) Rate (bpm): Volume (actual / calculated):
FCP (psi): Pump used for disp:X Yes No
Casing Rotated?X Yes No Reciprocated?X Yes No % Returns during job
Cement returns to surface?X Yes No Spacer returns?X Yes No Vol to Surf:
Cement In Place At: Date: Estimated TOC:
Method Used To Determine TOC:
Preflush (Spacer)
Type: Density (ppg) Volume pumped (BBLs)
Lead Slurry
Type:Sacks: Yield:
Density (ppg) Volume pumped (BBLs) Mixing / Pumping Rate (bpm):
Tail Slurry
Type:Sacks: Yield:
Density (ppg) Volume pumped (BBLs) Mixing / Pumping Rate (bpm):
Post Flush (Spacer)
Type: Density (ppg) Rate (bpm): Volume:
Displacement:
Type: Density (ppg) Rate (bpm): Volume (actual / calculated):
FCP (psi): Pump used for disp:X Yes No
Casing Rotated? Yes X No Reciprocated? Yes X No % Returns during job
Cement returns to surface?X Yes No Spacer returns?X Yes No Vol to Surf:
Cement In Place At: Date: Estimated TOC:
Method Used To Determine TOC:
Post Job Calculations:
Calculated Cmt Vol @ 0% excess: Total Volume cmt Pumped:
Cmt returned to surface: Calculated cement left in wellbore:
OH volume Calculated: OH volume actual: Actual % Washout:
Casing (Or Liner) Detail
Shoe
Cut joint
10 3/4
Passed
Size 11 W.P.5000
Test head to 3800 PSIG 10 MIN
456.5 20.4
WELLHEAD
Slip LockMake Type Serial No.FMC
379.2
SE
C
O
N
D
S
T
A
G
E
Rig
10:35
Cement to surface
Rotate Csg Recip Csg Ft. Min. PPG9.4
Shoe @ 6074 FC @ Top of Liner5,992.00
Floats Held
423.7 714
213 501
Spud Mud
OK
Remarks:
CASING RECORD
County State Alaska Supv.C.A. Demoski / I. Toomey
Hilcorp Energy Company
CASING & CEMENTING REPORT
Lease & Well No.MP I-30 Date Run 7-May-22
Setting Depths
Component Size Wt. Grade THD Make Length Bottom Top
TXP-BTC Innovex 1.60 6,074.00 6,072.40
23.67 56.20 32.539 5/8 47.0 L-80 TXP-BTC
Csg Wt. On Hook:275 Type Float Collar:Innovex No. Hrs to Run:17.5
9.5 4
1760
10
12 365 3.7
33.7
610
Bump Plug?
FI
R
S
T
S
T
A
G
E
10Tuned Spacer 6
15.8
820
2.9
9.4 6 161/160
445.3/445.6
1150
35
RIg
15.8 82
Bump press
Circulated cement to surface
Bump Plug?
Yes
8:14 5/8/2022 2,181
2181
3,074.003,084.00 5,950.00
CEMENTING REPORT
Csg Wt. On Slips:100
Spud Mud
60
711 2.88
Stage Collar @
60
Bump press
100
178
ES Cementer Closure OK
56
12 211
RKB to CHF
Type of Shoe:Innovex Casing Crew:Doyon
No. Jts. Delivered No. Jts. Run 148
Length Measurements W/O
Threads
Ftg. Delivered Ftg. Run 6,017.21 Ftg. Returned
Ftg. Cut Jt.17.78 Ftg. Balance
www.wellez.net WellEz Information Management LLC ver_04818br
3.45
ArcticCem
Type
79 total 9-5/8" x 12"1/4" bowspring centralizers ran. Two in shoe joint w/ stop rings 10' from each end. One floating on
joint #2. One each with stop rings mid-joint on joint #3 & 4.
One each on joints 5 to 25, every other joint to #49 then every third joint to #91. One each on joints #92 to 101. One
each with stop rings on pup joints above and below ES cementer.
One each on every third joint #104 to #146.
Casing 9 5/8 40.0 L-80 TXP-BTC Tenaris 80.63 6,072.40 5,991.77
Float Collar 10 3/4 TXP-BTC Innovex 1.33 5,991.77 5,990.44
Casing 9 5/8 40.0 L-80 TXP-BTC Tenaris 39.35 5,990.44 5,951.09
Baffle Adapter 10 3/4 TXP-BTC Halliburton 1.41 5,951.09 5,949.68
Casing 9 5/8 40.0 L-80 TXP-BTC Tenaris 3,750.51 5,949.68 2,199.17
Casing Pup Joint 9 5/8 40.0 L-80 TXP-BTC 18.10 2,199.17 2,181.07
ES Cementer 10 3/4 TXP-BTC Halliburton 2.82 2,181.07 2,178.25
Casing Pup Joint 9 5/8 40.0 L-80 TXP-BTC 16.78 2,178.25 2,161.47
Casing 9 5/8 47.0 L-80 TXP-BTC Tenaris 2,105.27 2,161.47 56.20
Type I/II Cement 504 2.33
Premium G cement 400 1.16
3.4
Premimum G 270 1.17
5/9/2022 34
Spud Mud
Cement to surface
100
X Y
X
2,181
33.7
MEMORANDUM State of Alaska
Alaska Oil and Gas Conservation Commission
DATE:Wednesday, July 20, 2022
SUBJECT:Mechanical Integrity Tests
TO:
FROM:Bob Noble
P.I. Supervisor
Petroleum Inspector
NON-CONFIDENTIAL
Hilcorp Alaska, LLC
I-30
MILNE PT UNIT I-30
Jim Regg
InspectorSrc:
Reviewed By:
P.I. Suprv
Comm ________
JBR 07/20/2022
I-30
50-029-23710-00-00
222-023-0
W
SPT
3936
2220230 1500
447 460 448 448
INITAL P
Bob Noble
6/9/2022
Monobore well.
30 MinPretestInitial15 Min
Well Name
Type Test
Notes:
Interval P/F
Well
Permit Number:
Type Inj TVD
PTD Test psi
API Well Number Inspector Name:MILNE PT UNIT I-30
Inspection Date:
Tubing
OA
Packer Depth
108 1657 1587 1569IA
45 Min 60 Min
Rel Insp Num:
Insp Num:mitRCN220612154427
BBL Pumped:2.8 BBL Returned:2.8
Wednesday, July 20, 2022 Page 1 of 1
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038,
37'
Submit to:
OOPERATOR:
FIEL DD // UNITT // PAD:
DATE:
OPERATORR REP:
AOGCCC REP:
Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min.
PTD 2220230 Type Inj N Tubing 0 0 0 0 Type Test P
Packer TVD 3935 BBL Pump 5.0 IA 0 2600 2525 2510 Interval O
Test psi 2500 BBL Return 5.0 OA Result P
Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min.
PTD Type Inj Tubing Type Test
Packer TVD BBL Pump IA Interval
Test psi BBL Return OA Result
Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min.
PTD Type Inj Tubing Type Test
Packer TVD BBL Pump IA Interval
Test psi BBL Return OA Result
Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min.
PTD Type Inj Tubing Type Test
Packer TVD BBL Pump IA Interval
Test psi BBL Return OA Result
Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min.
PTD Type Inj Tubing Type Test
Packer TVD BBL Pump IA Interval
Test psi BBL Return OA Result
Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min.
PTD Type Inj Tubing Type Test
Packer TVD BBL Pump IA Interval
Test psi BBL Return OA Result
Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min.
PTD Type Inj Tubing Type Test
Packer TVD BBL Pump IA Interval
Test psi BBL Return OA Result
Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min.
PTD Type Inj Tubing Type Test
Packer TVD BBL Pump IA Interval
Test psi BBL Return OA Result
TYPE INJ Codes TYPE TEST Codes
INTERVAL Codes Result Codes
W = Water P = Pressure Test I = Initial Test P = Pass
G = Gas O = Other (describe in Notes) 4 = Four Year Cycle F = Fail
S = Slurry V = Required by Variance I = Inconclusive
I = Industrial Wastewater O = Other (describe in notes)
N = Not Injecting
Notes:
Hilcorp Alaska LLC
Milne Point , MPU, I Pad
Douglas Yessak
05/21/22
Notes:Pre-Injection MIT-IA on rig. Witness waived by Brian Bixby. Monobore, No OA. Test to 2500 psi as per PTD.
Notes:
Notes:
Notes:
I -30
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
MMec hanicall Integrityy Tes t
jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov
Notes:
Notes:
Notes:
Form 10-426 (Revised 01/2017)2022-0521_MIT_MPU_I-30
9
9
9
9
9
9
-5HJJ
05/21/22
Pre-Injection MIT-IA Test to 2500 psi as per PTD.
David Douglas Hilcorp Alaska, LLC
Sr. Geotechnician 3800 Centerpoint Drive, Suite 1400
Anchorage, AK 99503
Tele: (907) 777-8337
E-mail: david.douglas@hilcorp.com
Please acknowledge receipt by signing and returning one copy of this transmittal.
Received By: Date:
Date: 05/23/2022
To: Alaska Oil & Gas Conservation Commission
Natural Resource Technician
333 W 7th Ave Suite 100
Anchorage, AK 99501
DATA TRANSMITTAL :
WELL: MPU I-30
PTD: 222-023
API: 50-029-23710-00-00
FINAL LWD FORMATION EVALUATION LOGS (05/02/2022 to 05/16/2022)
x EWR-M5, AGR, ABG, DGR, ADR, Horizontal Presentation (2” & 5” MD/TVD Color Logs)
x Final Definitive Directional Survey
x Final Geosteering and EOW Report/Plots
SFTP Transfer – Main Folders:
MPU I-30 LWD Subfolders:
MPU I-30 Geosteering Subfolders:
Please include current contact information if different from above.
PTD:222-023
T36643
Kayla Junke
Digitally signed by Kayla
Junke
Date: 2022.05.25 09:46:10
-08'00'
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038,
37'
STATE OF ALASKA
OIL AND GAS CONSERVATION COMMISSION
*All BOPE reports are due to the agency within 5 days of testing*
SSu b m i tt t o :jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov
Owner/Contractor: Rig No.:14 DATE: 5/10/22
Rig Rep.: Rig Phone: 670-3096
Operator: Op. Phone:670-3092
Rep.: E-Mail
Well Name: PTD #22220230 Sundry #
Operation: Drilling: x Workover: Explor.:
Test: Initial: x Weekly: Bi-Weekly: Other:
Rams:250-3000 Annular:250-3000 Valves:250-3000 MASP:1242
MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES:
Test Result Test Result Quantity Test Result
Location Gen.P Well Sign P Upper Kelly 1P
Housekeeping P Rig P Lower Kelly 1P
PTD On Location P Hazard Sec.P Ball Type 1P
Standing Order Posted P Misc.NA Inside BOP 1P
FSV Misc 0NA
BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm
Stripper 0NATrip Tank PP
Annular Preventer 1 13-5/8" 5K P Pit Level Indicators PP
#1 Rams 1 2-7/8" X 5" VBR P Flow Indicator PP
#2 Rams 1 Blinds P Meth Gas Detector PP
#3 Rams 1 2-7/8" X 5" VBR P H2S Gas Detector PP
#4 Rams 0NAMS Misc 0NA
#5 Rams 0NA
#6 Rams 0NA Quantity Test Result
Choke Ln. Valves 1 3-1/8" 5K P Inside Reel valves 0NA
HCR Valves 2 3-1/8" 5K P
Kill Line Valves 2 3-1/8" 5K P
Check Valve 0NAACCUMULATOR SYSTEM:
BOP Misc 0 NA Time/Pressure Test Result
System Pressure (psi)3000 P
CHOKE MANIFOLD:Pressure After Closure (psi)1600 P
Quantity Test Result 200 psi Attained (sec)45 P
No. Valves 14 P Full Pressure Attained (sec)199 P
Manual Chokes 1P Blind Switch Covers: All stations Yes
Hydraulic Chokes 1P Nitgn. Bottles # & psi (Avg.): 6 @ 2000 P
CH Misc 0NA ACC Misc 0NA
Test Results
Number of Failures:0 Test Time:6.0 Hours
Repair or replacement of equipment will be made within days.
Remarks:
AOGCC Inspection
24 hr Notice YES Date/Time 5-9-22/06:09
Waived By
Test Start Date/Time:5/10/2022 14:00
(date) (time)Witness
Test Finish Date/Time:5/10/2022 20:00
BOPE Test Report
Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov
Guy Cook
Doyon
Test Annular with 3-1/2" test joint to 250-3000 psi. Upper & Lower rams with 3-1/2" & 5" test joint. Draw down on BOP
functioned from both primary & remote controls. All tests preformed against Test plug.
J. Hansen / J. Charlie
Hilcorp
C. Demoski / I. Toomey
MPU I-30
Test Pressure (psi):
cdemoski@hilcorp.com
Form 10-424 (Revised 02/2022) 2022-0510_BOP_Doyon14_MPU_I-30
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CAUTION: This email originated from outside the State of Alaska mail system. Do not
click links or open attachments unless you recognize the sender and know the content
is safe.
From:Doug Yessak - (C)
To:Regg, James B (OGC);DOA AOGCC Prudhoe Bay;Brooks, Phoebe L (OGC)
Cc:Nathan Sperry;Ian Toomey - (C);Claude Demoski - (C)
Subject:Doyon 14 diverter 5-2-2022
Date:Monday, May 2, 2022 8:37:20 AM
Attachments:Diverter-Doyon 14_ 5-2-2022.xls
Doug Yessak
Hilcorp DSM
Doyon 14
907-670-3090
The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the
individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby
notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please
immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete
this message.
While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the
onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility
is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate.
038,
37'
Date: 5/2/2022 Development: X Exploratory:
Drlg Contractor: Rig No. 14 AOGCC Rep:
Operator:Oper. Rep:
Field/Unit/Well No.:Rig Rep:
PTD No.: 2220230 Rig Phone:
Rig Email:
MMISCELL ANEOUS:DIVERTER SYSTEM:
Location Gen.: P Well Sign: P Designed to Avoid Freeze-up? P
Housekeeping: P Drlg. Rig. P Remote Operated Diverter? P
Warning Sign P Misc: NA No Threaded Connections? P
24 hr Notice: P Vent line Below Diverter? P
AACCUMULATOR SYSTEM:Diverter Size: 21 1/4 in.
Systems Pressure: 2950 psig P Hole Size: 12 1/4 in.
Pressure After Closure: 1700 psig P Vent Line(s) Size: 16 in. P
200 psi Recharge Time: 35 Seconds P Vent Line(s) Length: 455 ft. P
Full Recharge Time:154 Seconds P Closest Ignition Source: 84 ft. P
Nitrogen Bottles (Number of): 6 Outlet from Rig Substructure: 446 ft. P
Avg. Pressure: 2100 psig P
Accumulator Misc: NA
Vent Line(s) Anchored: P
MMUD SYSTEM:Visual Alarm Turns Targeted / Long Radius: P
Trip Tank: P P Divert Valve(s) Full Opening: P
Mud Pits: P P Valve(s) Auto & Simultaneous:
Flow Monitor: P P Annular Closed Time: 27 sec P
Mud System Misc: 0 NA Knife Valve Open Time: 21 sec P
Diverter Misc: NA
GGAS DETECTORS:Visual Alarm
Methane: P P
Hydrogen Sulfide: P P
Gas Detectors Misc: 0 NA
Total Test Time: 1 hrs Non-Compliance Items:
Remarks:
Submit to:
SSTATE OF AL ASKA
AAL ASK A OIL AND GAS CONSERVATION COMMISSION
DDiv er t er Sys t em s In s p ec t i o n Rep o r t
GGENERAL INFORMATION
WaivedDoyon
phoebe.brooks@alaska.gov
Hilcorp
AOGCC Brian Bixby waived witness on 4-30-2022 @ 19:14 hrs. Function test performed utilizing a joint 5'' drill pipe, Rig electrician calibrated
and tested the gas alarms. Test PVT gain/loss and flow alarm.
0
Yessak / Toomey
Milne Point Unit I-30
rig14@doyondrilling.com
670-3096
AOGCC.Inspectors@alaska.gov
0
TTEST DATA
Hansen / Williams
TTEST DETAIL S
jim.regg@alaska.gov
Form 10-425 (Revised 11/2015)2022-0502_Diverter_Doyon14_MPU_I-30
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-5HJJ
Alaska Oil and Gas
Conservation Commission
333 West Seventh Avenue
Anchorage, Alaska 99501-3572
Main: 907.279.1433
Fax: 907.276.7542
www.aogcc.alaska.gov
Monty Myers
Drilling Manager
Hilcorp Alaska, LLC
3800 Centerpoint Dr., Suite 1400
Anchorage, AK, 99503
Re: Milne Point Field, Schrader Bluff Oil Pool, MPU I-30
Hilcorp Alaska, LLC
Permit to Drill Number: 222-023
Surface Location: 2333’ FSL, 3770’ FEL, Sec 33, T13N, R10E, Umiat
Bottomhole Location: 1821’ FNL, 519 FWL, Sec 21, T13N, R10E, Umiat
Dear Mr. Myers:
Enclosed is the approved application for the permit to drill the above referenced well.
This permit to drill does not exempt you from obtaining additional permits or an approval required
by law from other governmental agencies and does not authorize conducting drilling operations
until all other required permits and approvals have been issued. In addition, the AOGCC reserves
the right to withdraw the permit in the event it was erroneously issued.
Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska
Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply
with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code,
or an AOGCC order, or the terms and conditions of this permit may result in the revocation or
suspension of the permit.
Sincerely,
Jeremy M. Price
Chair
DATED this ___ day of March, 2022.
Jeremy
Price
Digitally signed by
Jeremy Price
Date: 2022.03.07
10:24:03 -09'00'
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3.1.2022
By Samantha Carlisle at 11:57 am, Mar 01, 2022
'LJLWDOO\VLJQHGE\0RQW\00\HUV
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- BOPE test to 3000 psi. Annular to 2500 psi.
- State witnessed MIT-IA to 2500 psi.
DSR-3/1/22
50-029-23710-00-00
SFD
SFD 3/2/2022
GE\0RQW\00\HUVJ\J
'1 FQ 0RQW\0'1 FQ 0RQ'1 FQ 0RQ
222-023
MGR07MAR2022
- See following page for conditions of approval.
dts 3/7/2022
Jeremy Price Digitally signed by Jeremy Price
Date: 2022.03.07 10:25:37 -09'00'
3/7/2022
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Milne Point Unit
I-30 SB Injector
Drilling Procedure
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Milne Point Unit
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Drilling Procedure
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Milne Point Unit
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Drilling Procedure
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Milne Point Unit
I-30 SB Injector
Drilling Procedure
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Milne Point Unit
I-30 SB Injector
Drilling Procedure
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Milne Point Unit
I-30 SB Injector
Drilling Procedure
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Milne Point Unit
I-30 SB Injector
Drilling Procedure
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Milne Point Unit
I-30 SB Injector
Drilling Procedure
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Milne Point Unit
I-30 SB Injector
Drilling Procedure
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Milne Point Unit
I-30 SB Injector
Drilling Procedure
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Milne Point Unit
I-30 SB Injector
Drilling Procedure
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Send final “As-Run” casing tally & casing and cement report to nathan.sperry@hilcorp.com and
joseph.lastufka@hilcorp.com This will be included with the EOW documentation that goes to the
AOGCC.
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Milne Point Unit
I-30 SB Injector
Drilling Procedure
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Milne Point Unit
I-30 SB Injector
Drilling Procedure
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email: Melvin.Rixse@alaska.gov
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Milne Point Unit
I-30 SB Injector
Drilling Procedure
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14823.06' MD, 4107.87'TVDStart Dir 2º/100' : 15007.68' MD, 4114.1'TVDEnd Dir : 15122.4' MD, 4117.3' TVDStart Dir 2º/100' : 15512.1' MD, 4135.7'TVDEnd Dir : 15798.58' MD, 4141.81' TVDStart Dir 2º/100' : 15843.99' MD, 4140.73'TVDEnd Dir : 16116.88' MD, 4141.37' TVDTotal Depth : 16491.88' MD, 4152.1' TVDSV3BPRFUG3 CoalLA3LA2LA1UG_MAUG MBUG MDUG MESB NASB NBSB NCSB NESB OAHilcorp Alaska, LLCCalculation Method:Minimum CurvatureError System:ISCWSAScan Method: Closest Approach 3DError Surface: Ellipsoid SeparationWarning Method: Error RatioWELL DETAILS: Plan: MPU I-30i33.40+N/-S+E/-WNorthingEastingLatitudeLongitude0.000.006009448.35551600.28 70° 26' 11.620 N 149° 34' 45.458 WSURVEY PROGRAMDate: 2022-01-31T00:00:00 Validated: Yes Version: Depth From Depth To Survey/Plan Tool33.70 1000.00 MPU I-30 wp11 (MPU I-30i) GYD_Quest GWD1000.00 6260.00 MPU I-30 wp11 (MPU I-30i) 3_MWD+IFR2+MS+Sag6260.00 16491.88 MPU I-30 wp11 (MPU I-30i) 3_MWD+IFR2+MS+SagFORMATION TOP DETAILSTVDPath TVDssPath MDPath Formation1349.71 1282.61 1434.34 SV31793.58 1726.48 2013.20 BPRF2190.61 2123.51 2578.10 UG3 Coal2617.84 2550.74 3216.36 LA32940.36 2873.26 3698.19 LA23260.05 3192.95 4180.43 LA13489.04 3421.94 4556.24 UG_MA3561.71 3494.61 4688.02 UG MB3653.89 3586.79 4870.29 UG MD3717.10 3650.00 5009.86 UG ME3740.31 3673.21 5065.37 SB NA3770.10 3703.00 5141.07 SB NB3793.10 3726.00 5203.80 SB NC3877.10 3810.00 5488.33 SB NE3933.26 3866.16 5865.33 SB OAREFERENCE INFORMATIONCo-ordinate (N/E) Reference:Well Plan: MPU I-30i, True NorthVertical (TVD) Reference:MPU I-30 As-staked D14 RKB @ 67.10usftMeasured Depth Reference:MPU I-30 As-staked D14 RKB @ 67.10usftCalculation Method:Minimum CurvatureProject:Milne PointSite:M Pt I PadWell:Plan: MPU I-30iWellbore:MPU I-30iDesign:MPU I-30 wp11CASING DETAILSTVD TVDSS MD SizeName3933.09 3865.99 6260.00 9-5/8 9 5/8" x 12 1/4"4152.10 4085.00 16491.88 4-1/2 4 1/2" x 8 1/2"SECTION DETAILSSec MD Inc Azi TVD +N/-S +E/-W Dleg TFace VSect Target Annotation1 33.70 0.00 0.00 33.70 0.00 0.00 0.00 0.00 0.002 256.10 0.00 0.00 256.10 0.00 0.00 0.00 0.00 0.00 Start Dir 3º/100' : 256.1' MD, 256.1'TVD3 556.10 9.00 210.00 554.87 -20.36 -11.76 3.00 210.00 -22.10 Start Dir 4º/100' : 556.1' MD, 554.87'TVD4 806.10 19.00 210.00 797.13 -72.67 -41.96 4.00 0.00 -78.865 1206.10 31.66 233.72 1158.83 -191.95 -159.90 4.00 50.00 -216.806 1713.78 41.50 264.00 1569.33 -289.38 -437.49 4.00 74.28 -360.95 End Dir : 1713.78' MD, 1569.33' TVD7 2063.78 41.50 264.00 1831.46 -313.62 -668.14 0.00 0.00 -424.88 Start Dir 4º/100' : 2063.78' MD, 1831.46'TVD8 2407.97 47.98 281.33 2076.73 -300.36 -908.07 4.00 68.39 -453.48 End Dir : 2407.97' MD, 2076.73' TVD9 3903.52 47.98 281.33 3077.80 -82.14 -1997.52 0.00 0.00 -427.76 Start Dir 4º/100' : 3903.52' MD, 3077.8'TVD10 6034.43 91.00 4.00 3937.03 1424.75 -2865.69 4.00 84.34 905.48 End Dir : 6034.43' MD, 3937.03' TVD11 6259.43 91.00 4.00 3933.10 1649.17 -2850.00 0.00 0.00 1129.22 Start Dir 2º/100' : 6259.43' MD, 3933.1'TVD12 6433.51 88.21 6.09 3934.30 1822.55 -2834.70 2.00 143.20 1302.62 End Dir : 6433.51' MD, 3934.3' TVD13 6631.63 88.21 6.09 3940.48 2019.46 -2813.71 0.00 0.00 1500.18 Start Dir 2º/100' : 6631.63' MD, 3940.48'TVD14 6751.12 90.60 6.00 3941.72 2138.26 -2801.13 2.00 -2.06 1619.37 End Dir : 6751.12' MD, 3941.72' TVD15 7001.12 90.60 6.00 3939.10 2386.88 -2775.00 0.00 0.00 1868.74 Start Dir 2.5º/100' : 7001.12' MD, 3939.1'TVD16 7215.03 85.28 6.50 3946.80 2599.31 -2751.75 2.50 174.70 2081.98 End Dir : 7215.03' MD, 3946.8' TVD17 7402.88 85.28 6.50 3962.27 2785.32 -2730.57 0.00 0.00 2268.84 Start Dir 2.5º/100' : 7402.88' MD, 3962.27'TVD18 7592.91 90.00 6.00 3970.10 2974.00 -2709.91 2.50 -5.99 2458.25 End Dir : 7592.91' MD, 3970.1' TVD19 7642.91 90.00 6.00 3970.10 3023.73 -2704.69 0.00 0.00 2508.13 MPU I-30i wp07 tgt 06 L Start Dir 2.5º/100' : 7642.91' MD, 3970.1'TVD20 7862.76 93.98 2.21 3962.46 3242.80 -2688.96 2.50 -43.51 2726.60 End Dir : 7862.76' MD, 3962.46' TVD21 7922.47 93.98 2.21 3958.31 3302.32 -2686.66 0.00 0.00 2785.62 Start Dir 2.5º/100' : 7922.47' MD, 3958.31'TVD22 8120.19 90.48 5.70 3950.61 3499.36 -2673.03 2.50 135.05 2982.03 End Dir : 8120.19' MD, 3950.61' TVD23 8300.19 90.48 5.70 3949.10 3678.46 -2655.15 0.00 0.00 3161.52 MPU I-30i wp07 tgt 08 U Start Dir 2.5º/100' : 8300.19' MD, 3949.1'TVD24 8621.39 92.92 13.35 3939.56 3994.84 -2602.07 2.50 72.22 3482.30 End Dir : 8621.39' MD, 3939.56' TVD25 8637.59 92.92 13.35 3938.73 4010.58 -2598.33 0.00 0.00 3498.45 Start Dir 2.5º/100' : 8637.59' MD, 3938.73'TVD26 8882.61 87.50 10.50 3937.83 4250.19 -2547.72 2.50 -152.21 3743.21 End Dir : 8882.61' MD, 3937.83' TVD27 9232.61 87.50 10.50 3953.10 4594.00 -2484.00 0.00 0.00 4092.86 Start Dir 2.5º/100' : 9232.61' MD, 3953.1'TVD28 9405.00 84.47 7.43 3965.17 4763.83 -2457.20 2.50 -134.76 4264.76 End Dir : 9405' MD, 3965.17' TVD29 9703.41 84.47 7.43 3993.93 5058.36 -2418.81 0.00 0.00 4561.49 Start Dir 2.5º/100' : 9703.41' MD, 3993.93'TVD30 9824.00 87.34 6.50 4002.54 5177.74 -2404.23 2.50 -17.89 4681.59 End Dir : 9824' MD, 4002.54' TVD31 10224.00 87.34 6.50 4021.10 5574.74 -2359.00 0.00 0.00 5080.41 Start Dir 2.5º/100' : 10224' MD, 4021.1'TVD32 10337.42 88.86 4.11 4024.86 5687.60 -2348.53 2.50 -57.61 5193.38 End Dir : 10337.42' MD, 4024.86' TVD33 10368.84 88.86 4.11 4025.48 5718.93 -2346.28 0.00 0.00 5224.62 Start Dir 2.5º/100' : 10368.84' MD, 4025.48'TVD34 10432.86 89.00 5.70 4026.68 5782.70 -2340.81 2.50 85.02 5288.37 MPU I-30i wp07 tgt 13 Interp35 10923.27 91.18 17.77 4025.90 6261.95 -2241.28 2.50 79.78 5777.62 End Dir : 10923.27' MD, 4025.9' TVD36 10959.43 91.18 17.77 4025.16 6296.38 -2230.24 0.00 0.00 5813.45 Start Dir 2.5º/100' : 10959.43' MD, 4025.16'TVD37 11427.20 89.14 6.25 4023.85 6753.12 -2133.10 2.50 -100.00 6280.12 End Dir : 11427.2' MD, 4023.85' TVD38 11777.20 89.14 6.25 4029.10 7101.00 -2095.00 0.00 0.00 6629.33 Start Dir 2º/100' : 11777.2' MD, 4029.1'TVD39 11928.92 87.68 8.91 4033.32 7251.32 -2075.00 2.00 118.87 6780.84 End Dir : 11928.92' MD, 4033.32' TVD40 12244.24 87.68 8.91 4046.10 7562.58 -2026.21 0.00 0.00 7095.84 MPU I-30i wp07 tgt 18 U Start Dir 2º/100' : 12244.24' MD, 4046.1'TVD41 12575.37 86.34 15.40 4063.40 7885.67 -1956.62 2.00 101.79 7426.11 End Dir : 12575.37' MD, 4063.4' TVD42 12595.63 86.34 15.40 4064.69 7905.16 -1951.25 0.00 0.00 7446.23 Start Dir 2º/100' : 12595.63' MD, 4064.69'TVD43 12728.01 88.64 14.09 4070.49 8033.04 -1917.59 2.00 -29.78 7578.02 End Dir : 12728.01' MD, 4070.49' TVD44 13428.01 88.64 14.09 4087.10 8711.79 -1747.22 0.00 0.00 8276.04 MPU I-30i wp07 tgt 22 L Start Dir 2.5º/100' : 13428.01' MD, 4087.1'TVD45 13590.60 91.55 11.25 4086.83 8870.39 -1711.56 2.50 -44.25 8438.42 End Dir : 13590.6' MD, 4086.83' TVD46 13845.73 91.55 11.25 4079.92 9120.52 -1661.79 0.00 0.00 8693.39 Start Dir 2.5º/100' : 13845.73' MD, 4079.92'TVD47 13979.50 88.70 13.00 4079.62 9251.28 -1633.69 2.50 148.52 8827.05 End Dir : 13979.5' MD, 4079.62' TVD48 14529.50 88.70 13.00 4092.10 9787.05 -1510.00 0.00 0.00 9376.15 Start Dir 2.5º/100' : 14529.5' MD, 4092.1'TVD49 14614.14 86.62 13.40 4095.55 9869.39 -1490.69 2.50 169.19 9460.59 End Dir : 14614.14' MD, 4095.55' TVD50 14823.06 86.62 13.40 4107.87 10072.27 -1442.37 0.00 0.00 9668.78 Start Dir 2.5º/100' : 14823.06' MD, 4107.87'TVD51 15007.68 89.51 17.00 4114.10 10250.28 -1394.00 2.50 51.33 9852.49 Start Dir 2º/100' : 15007.68' MD, 4114.1'TVD52 15122.40 87.29 16.41 4117.30 10360.10 -1361.04 2.00 -165.09 9966.36 End Dir : 15122.4' MD, 4117.3' TVD53 15512.10 87.29 16.41 4135.70 10733.51 -1251.08 0.00 0.00 10353.20 Start Dir 2º/100' : 15512.1' MD, 4135.7'TVD54 15582.66 87.19 15.00 4139.10 10801.36 -1232.00 2.00 -94.22 10423.3355 15798.58 91.37 16.08 4141.81 11009.32 -1174.16 2.00 14.53 10638.17 End Dir : 15798.58' MD, 4141.81' TVD56 15843.99 91.37 16.08 4140.73 11052.94 -1161.59 0.00 0.00 10683.31 Start Dir 2º/100' : 15843.99' MD, 4140.73'TVD57 16116.88 88.36 11.53 4141.37 11317.85 -1096.49 2.00 -123.46 10955.50 End Dir : 16116.88' MD, 4141.37' TVD58 16491.88 88.36 11.53 4152.10 11685.13 -1021.56 0.00 0.00 11330.21 MPU I-30i wp07 tgt 31 U Total Depth : 16491.88' MD, 4152.1' TVD
-1500
-750
0
750
1500
2250
3000
3750
4500
5250
6000
6750
7500
8250
9000
9750
10500
11250
12000
12750
South(-)/North(+) (1500 usft/in)-4500 -3750 -3000 -2250 -1500 -750 0 750 1500 2250 3000 3750 4500 5250 6000
West(-)/East(+) (1500 usft/in)
MPU I-30i wp07 tgt 13 Interp
MPU I-30i wp07 tgt 12 L
MPU I-30i wp07 tgt 11 L
MPU I-30i wp07 tgt 10 U
MPU I-30i wp07 tgt 09 U
MPU I-30i wp07 tgt 08 U
MPU I-30i wp07 tgt 07 U
MPU I-30i wp07 tgt 06 L
MPU I-30i wp07 tgt 05 L
MPU I-30i wp07 tgt 04 L
MPU I-30i wp07 tgt 04 Interp
MPU I-30i wp07 tgt 03 L
MPU I-30i wp07 tgt 02 U
MPU I-30i wp07 tgt 01 U
MPU I-30i wp09 tgt 01 U
MPU I-30i wp07 tgt 31 U
MPU I-30i wp07 tgt 30 U
MPU I-30i wp07 tgt 29 L
MPU I-30i wp07 tgt 28 L
MPU I-30i wp07 tgt 27 L
MPU I-30i wp07 tgt 26 L
MPU I-30i wp07 tgt 25 U
MPU I-30i wp07 tgt 24 U
MPU I-30i wp07 tgt 23 U
MPU I-30i wp07 tgt 22 L
MPU I-30i wp07 tgt 21 L
MPU I-30i wp07 tgt 20 L
MPU I-30i wp07 tgt 19 L
MPU I-30i wp07 tgt 18 U
MPU I-30i wp07 tgt 17 U
MPU I-30i wp07 tgt 16 U
MPU I-30i wp07 tgt 15 U
MPU I-30i wp07 tgt 14 U
MPU I-30i wp07 tgt 13 L
9 5/8" x 12 1/4"
4 1/2" x 8 1/2"
2505007501
0
0
012
501500175020002250250027503000325035003 7 5 0
4000
4152
MPU I-30 wp11
Start Dir 3º/100' : 256.1' MD, 256.1'TVD
Start Dir 4º/100' : 556.1' MD, 554.87'TVD
End Dir : 1713.78' MD, 1569.33' TVD
Start Dir 4º/100' : 2063.78' MD, 1831.46'TVD
End Dir : 2407.97' MD, 2076.73' TVD
Start Dir 4º/100' : 3903.52' MD, 3077.8'TVD
End Dir : 6034.43' MD, 3937.03' TVD
Start Dir 2º/100' : 6259.43' MD, 3933.1'TVD
End Dir : 6433.51' MD, 3934.3' TVD
Start Dir 2º/100' : 6631.63' MD, 3940.48'TVD
End Dir : 6751.12' MD, 3941.72' TVD
Start Dir 2.5º/100' : 7001.12' MD, 3939.1'TVD
End Dir : 7215.03' MD, 3946.8' TVD
Start Dir 2.5º/100' : 7402.88' MD, 3962.27'TVD
End Dir : 7592.91' MD, 3970.1' TVD
Start Dir 2.5º/100' : 7642.91' MD, 3970.1'TVD
End Dir : 7862.76' MD, 3962.46' TVD
Start Dir 2.5º/100' : 7922.47' MD, 3958.31'TVD
End Dir : 8120.19' MD, 3950.61' TVD
Start Dir 2.5º/100' : 8300.19' MD, 3949.1'TVD
End Dir : 8621.39' MD, 3939.56' TVD
Start Dir 2.5º/100' : 8637.59' MD, 3938.73'TVD
End Dir : 8882.61' MD, 3937.83' TVD
Start Dir 2.5º/100' : 9232.61' MD, 3953.1'TVD
End Dir : 9405' MD, 3965.17' TVD
Start Dir 2.5º/100' : 9703.41' MD, 3993.93'TVD
End Dir : 9824' MD, 4002.54' TVD
Start Dir 2.5º/100' : 10224' MD, 4021.1'TVD
End Dir : 10337.42' MD, 4024.86' TVD
Start Dir 2.5º/100' : 10368.84' MD, 4025.48'TVD
End Dir : 10923.27' MD, 4025.9' TVD
Start Dir 2.5º/100' : 10959.43' MD, 4025.16'TVD
End Dir : 11427.2' MD, 4023.85' TVD
Start Dir 2º/100' : 11777.2' MD, 4029.1'TVD
End Dir : 11928.92' MD, 4033.32' TVD
Start Dir 2º/100' : 12244.24' MD, 4046.1'TVD
End Dir : 12575.37' MD, 4063.4' TVD
Start Dir 2º/100' : 12595.63' MD, 4064.69'TVD
End Dir : 12728.01' MD, 4070.49' TVD
Start Dir 2.5º/100' : 13428.01' MD, 4087.1'TVD
End Dir : 13590.6' MD, 4086.83' TVD
Start Dir 2.5º/100' : 13845.73' MD, 4079.92'TVD
End Dir : 13979.5' MD, 4079.62' TVD
Start Dir 2.5º/100' : 14529.5' MD, 4092.1'TVD
End Dir : 14614.14' MD, 4095.55' TVD
Start Dir 2.5º/100' : 14823.06' MD, 4107.87'TVD
Start Dir 2º/100' : 15007.68' MD, 4114.1'TVD
End Dir : 15122.4' MD, 4117.3' TVD
Start Dir 2º/100' : 15512.1' MD, 4135.7'TVD
End Dir : 15798.58' MD, 4141.81' TVD
Start Dir 2º/100' : 15843.99' MD, 4140.73'TVD
End Dir : 16116.88' MD, 4141.37' TVD
Total Depth : 16491.88' MD, 4152.1' TVD
CASING DETAILS
TVD TVDSS MD Size Name
3933.09 3865.99 6260.00 9-5/8 9 5/8" x 12 1/4"
4152.10 4085.00 16491.88 4-1/2 4 1/2" x 8 1/2"
Project: Milne Point
Site: M Pt I Pad
Well: Plan: MPU I-30i
Wellbore: MPU I-30i
Plan: MPU I-30 wp11
WELL DETAILS: Plan: MPU I-30i
33.40
+N/-S +E/-W Northing Easting Latitude Longitude
0.00 0.00 6009448.35 551600.28 70° 26' 11.620 N 149° 34' 45.458 W
REFERENCE INFORMATION
Co-ordinate (N/E) Reference:Well Plan: MPU I-30i, True North
Vertical (TVD) Reference: MPU I-30 As-staked D14 RKB @ 67.10usft
Measured Depth Reference:MPU I-30 As-staked D14 RKB @ 67.10usft
Calculation Method:Minimum Curvature
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0.001.002.003.004.00Separation Factor0 325 650 975 1300 1625 1950 2275 2600 2925 3250 3575 3900 4225 4550 4875 5200 5525 5850 6175Measured Depth (650 usft/in)No-Go Zone - Stop DrillingCollision Avoidance RequiredCollision Risk Procedures Req.WELL DETAILS:Plan: MPU I-30i NAD 1927 (NADCON CONUS)Alaska Zone 0433.40+N/-S +E/-W NorthingEastingLatitudeLongitude0.000.006009448.35551600.2870° 26' 11.620 N149° 34' 45.458 WREFERENCE INFORMATIONCo-ordinate (N/E) Reference:Well Plan: MPU I-30i, True NorthVertical (TVD) Reference: MPU I-30 As-staked D14 RKB @ 67.10usftMeasured Depth Reference:MPU I-30 As-staked D14 RKB @ 67.10usftCalculation Method:Minimum CurvatureSURVEY PROGRAMDate: 2022-01-31T00:00:00 Validated: Yes Version: Depth From Depth To Survey/PlanTool33.70 1000.00 MPU I-30 wp11 (MPU I-30i) GYD_Quest GWD1000.00 6260.00 MPU I-30 wp11 (MPU I-30i) 3_MWD+IFR2+MS+Sag6260.00 16491.88 MPU I-30 wp11 (MPU I-30i) 3_MWD+IFR2+MS+Sag0.0030.0060.0090.00120.00150.00180.00Centre to Centre Separation (60.00 usft/in)0 325 650 975 1300 1625 1950 2275 2600 2925 3250 3575 3900 4225 4550 4875 5200 5525 5850 6175Measured Depth (650 usft/in)MPU I-22 wp03MPU I-29 wp08aMPI-09MPI-10MPU I-28iMPI-01MPI-06MPI-02MPU I-21iMPI-15MPU I-31 wp03MPI-08MPU I-38MPU I-38MPU I-39iMPI-04MPI-16MPI-07MPU I-36MPI-11MPI-17NO GLOBAL FILTER: Using user defined selection & filtering criteria33.70 To 16491.88Project: Milne PointSite: M Pt I PadWell: Plan: MPU I-30iWellbore: MPU I-30iPlan: MPU I-30 wp11Ladder / S.F. Plots1 of 2CASING DETAILSTVD TVDSS MD Size Name3933.09 3865.99 6260.00 9-5/8 9 5/8" x 12 1/4"4152.10 4085.00 16491.88 4-1/2 4 1/2" x 8 1/2"
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0.001.002.003.004.00Separation Factor6000 6600 7200 7800 8400 9000 9600 10200 10800 11400 12000 12600 13200 13800 14400 15000 15600 16200 16800Measured Depth (1200 usft/in)MPU I-29 wp08aMPJ-22MPJ-08AMPJ-08MPU I-37iMPU I-37PB1MPI-19L1MPJ-19AMPJ-26L2MPU I-31 wp03MPI-08MPU I-39iNo-Go Zone - Stop DrillingCollision Avoidance RequiredCollision Risk Procedures Req.WELL DETAILS:Plan: MPU I-30i NAD 1927 (NADCON CONUS)Alaska Zone 0433.40+N/-S +E/-W Northing Easting Latitude Longitude0.000.00 6009448.35551600.2870° 26' 11.620 N149° 34' 45.458 WREFERENCE INFORMATIONCo-ordinate (N/E) Reference:Well Plan: MPU I-30i, True NorthVertical (TVD) Reference: MPU I-30 As-staked D14 RKB @ 67.10usftMeasured Depth Reference:MPU I-30 As-staked D14 RKB @ 67.10usftCalculation Method:Minimum CurvatureSURVEY PROGRAMDate: 2022-01-31T00:00:00 Validated: Yes Version: Depth From Depth To Survey/PlanTool33.70 1000.00 MPU I-30 wp11 (MPU I-30i) GYD_Quest GWD1000.00 6260.00 MPU I-30 wp11 (MPU I-30i) 3_MWD+IFR2+MS+Sag6260.00 16491.88 MPU I-30 wp11 (MPU I-30i) 3_MWD+IFR2+MS+Sag0.0030.0060.0090.00120.00150.00180.00Centre to Centre Separation (60.00 usft/in)6000 6600 7200 7800 8400 9000 9600 10200 10800 11400 12000 12600 13200 13800 14400 15000 15600 16200 16800Measured Depth (1200 usft/in)MPJ-08AMPJ-19AMPJ-09ANO GLOBAL FILTER: Using user defined selection & filtering criteria33.70 To 16491.88Project: Milne PointSite: M Pt I PadWell: Plan: MPU I-30iWellbore: MPU I-30iPlan: MPU I-30 wp11CASING DETAILSTVD TVDSS MD Size Name3933.09 3865.99 6260.00 9-5/8 9 5/8" x 12 1/4"4152.10 4085.00 16491.88 4-1/2 4 1/2" x 8 1/2"Ladder / S.F. Plots2 of 2
Revised 2/2015
TRANSMITTAL LETTER CHECKLIST
WELL NAME: ______________________________________
PTD: _____________________________________________
___ Development ___ Service ___ Exploratory ___ Stratigraphic Test ___ Non-Conventional
FIELD: ____________________________ POOL: ______________________________________
Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter
CHECK OPTIONS TEXT FOR APPROVAL LETTER
MULTI
LATERAL
(If last two digits
in API number are
between 60-69)
The permit is for a new wellbore segment of existing well Permit
No. _____________, API No. 50-_______________________.
Production should continue to be reported as a function of the original
API number stated above.
Pilot Hole
In accordance with 20 AAC 25.005(f), all records, data and logs
acquired for the pilot hole must be clearly differentiated in both
well name (_______________________PH) and API number
(50-_____________________) from records, data and logs acquired for
well (name on permit).
Spacing
Exception
The permit is approved subject to full compliance with 20 AAC 25.055.
Approval to produce/inject is contingent upon issuance of
a conservation order approving a spacing exception.
(_____________________________) as Operator assumes the liability
of any protest to the spacing exception that may occur.
Dry Ditch Sample
All dry ditch sample sets submitted to the AOGCC must be in no greater
than 30' sample intervals from below the permafrost or from where
samples are first caught and 10' sample intervals through target zones.
Non-
Conventional
Well
Please note the following special condition of this permit:
Production or production testing of coal bed methane is not allowed for
well ( ) until after ( )
has designed and implemented a water well testing program to provide
baseline data on water quality and quantity.
(________________________) must contact the AOGCC to obtain
advance approval of such water well testing program.
Well Logging
Requirements
Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types
of well logs to be run. In addition to the well logging program proposed
by (_______________________________) in the attached application,
the following well logs are also required for this well:
Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071,
composite curves for well logs run must be submitted to the AOGCC
within 90 days after completion, suspension or abandonment of this
well.
222-023
MPU I-30
Schrader Bluff OilMilne Point Unit
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