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Austin Chalk

All things about Austin Chalk in Louisiana: Horizontal drilling, improved seismic testing, and liner casing are offering hope for the deep minerals in the Austin Chalk which runs from Austin, Texas through parts of Louisiana to Biloxi Mississippi.

Location: Vernon-Rapides-Avoyelles-StLandry-PtCoupee-Florida parishes
Members: 259
Latest Activity: Jul 9

FROM oilprice.com Where Will U.S. Frackers Drill Next? By Tsvetana Paraskova - Jun 18, 2018, 6:00 PM CDT

Discussion Forum

Prime Rock HZ AC Application, Sugartown Field

Started by Skip Peel - Independent Landman Jul 9.

Profit Island Field - New Pennington Austin Chalk Unit 19 Replies

Started by Diamond Jim. Last reply by Rock Man Jul 6.

New Vernon Parish Horizontal AC Well Permitted 69 Replies

Started by Skip Peel - Independent Landman. Last reply by Skip Peel - Independent Landman Mar 11.

Oil & Gas Industry Jobs

Started by Lisa Melder-Johnson Feb 21.

Additional Pennington Austin Chalk Units - Profit Island and Morganza Fields 16 Replies

Started by Diamond Jim. Last reply by Rock Man Feb 10.

PROPOSED SOUTHWIND AC UNITS (3 MASTERS CREEK & 2 WEST CHENEYVILLE) 7 Replies

Started by Skip Peel - Independent Landman. Last reply by Lisa Melder-Johnson Jan 29.

Southwind AC Units formed in Maters Creek Field, Evangeline and Rapides parishes 44 Replies

Started by Skip Peel - Independent Landman. Last reply by Darrell Blanchard Jan 19.

PRIZE EXPLORATION & PRODUCTION - AUSC RA SUA;MAUR H #1 1 Reply

Started by Skip Peel - Independent Landman. Last reply by Kay B Dec 18, 2019.

Torrent Oil AC Wells 52 Replies

Started by Skip Peel - Independent Landman. Last reply by Skip Peel - Independent Landman Nov 20, 2019.

The resurgence of the Louisiana Austin Chalk 738 Replies

Started by Craig Wascom. Last reply by Skip Peel - Independent Landman Nov 2, 2019.

Louisiana Austin Chalk: Hundreds of Millions Down the Drain? 34 Replies

Started by Skip Peel - Independent Landman. Last reply by Skip Peel - Independent Landman Oct 22, 2019.

EOG Drilling Permit - Pointe Coupee 117 Replies

Started by Les Miles. Last reply by Rock Man Sep 19, 2019.

COP AUS C RA SUA;ERWIN 1 Reply

Started by John Matherne. Last reply by Rock Man Aug 27, 2019.

Petroquest AC Well Permit in Lacour Field, Pointe Coupee 26 Replies

Started by Skip Peel - Independent Landman. Last reply by William C. Morrison Aug 1, 2019.

ConocoPhillips disappointed in Louisiana Austin Chalk 10 Replies

Started by Skip Peel - Independent Landman. Last reply by Rock Man Aug 1, 2019.

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Comment by Rock Man on June 25, 2020 at 16:57

What we don't know (and never will know) are the details of the monthly production over time. Water rates, choke sizes, etc. Believe me, if the rates were such on this well that it was still economic, the well would not be shut in.

The IP rate works out to a 5.9% oil cut (210 BO & 3343 BW). If the same oil to water ratio was maintained, the 1000 BOPD rate would equate to almost 17,000 BW per day. The unknown facts are the key to understanding what is doing on here.

Comment by Skip Peel - Independent Landman on June 25, 2020 at 15:11

Allowables, as far as I know, are based on state flow tests.  There is no DT-1 test entered in the SONRIS Well File so I think that test would look much like the IP data:

COMPLETED 1/21/2020 AS AN OIL WELL W/ 210 BOPD; 1650 MCFD; 8200 FTP; 6063 SITP; 1300 CP; 18/64" CK; 3343 BWPD; 94% BS&W; 7857; GVTY 52 API; PERF: 16,157'-22,372'

Without a DT-1 date it is impossible to know how soon the test was done after the well was allowed to flow into a sales line.  So did oil and gas flow improve because the well "cleaned up" over time?  The lateral is 6215 linear feet.

Comment by Rock Man on June 25, 2020 at 12:20
Remember how high the initial water rate was on this well (10,000 bpd?). That info is not posted with monthly production. And I think the recent allowable posting is just the regular posting that state puts out regardless of well status. Skip may know more about that process.
Comment by David Crockett on June 25, 2020 at 12:02

I also saw on this well that they have posted an allowable and an estimated potential for July. Does that mean they have opened the well back up. There weren’t any allowable posted since March until the one for July. 

Comment by Skip Peel - Independent Landman on June 25, 2020 at 10:54

Looks correct, hope it is at 1000 barrels a day for February ( a 28 day period).  If the reported volume is correct, it makes the recent work order on the LM 3H seem a little puzzling.

WORK PERMITS

REFERENCE NUMBER APPLICATION DATE EXPIRATION DATE WORK PERMIT TYPE WORK PERMIT STATUS WORK PERMIT STATUS_DATE TOTAL DEPTH WORK_PERFORMED DOCUMENTATION RECEIPT DATE TEST SAND WORK DESCRIPTION
20-034 03/10/2020 03/10/2021 PLUG AND ABANDON VERBAL 03/11/2020 0 N TEMPORARILY ABANDON TA WELL. SET EZSV @ 14,242'. SQZ 86.4 BBLS BLW EZSV & LEAVE 3.6 BBLS ON TOP. SET BP @ 5300' & LEAVE 200' CMT ON TOP. SET BP @ 500' & SET 100' CMT ON TOP. N/D BOP & LEAVE WH IN PLACE.
Comment by Hydrocarbonite on June 25, 2020 at 10:44

just reviewed production numbers on Crowell #2 on Sonris.  are those real?

02/01/2020

oil 28025

gas 202968

Comment by Hydrocarbonite on June 25, 2020 at 10:37

RPT DATE LUW CODE STORAGE FAC DOC USE WELL CNT OPENING STK OIL PROD(BBL) GAS PROD(MCF) DISPOSITION CLOSING STK PARISH
02/01/2020 052211 1 1530 28025 202968 27795 1760 RAPIDES
01/01/2020 052211 1 0 6011 47298 4481 1530 RAPIDES
CASING

Comment by Rock Man on June 1, 2020 at 15:58

By "cooler" I wonder if this was a surface unit to remove NGL's from gas stream via refrigeration approach (e.g. JT Unit). Having only 5 bbls (slightly over 200 gallons) of "spill" not a big deal based on my oilfield experiences. To temporarily abandon the wellbore because of this doesn't make a lot of sense to me. I may be missing something.

Comment by David Crockett on June 1, 2020 at 15:51

I see that on the crowell lm 30H Number 2 the cooler erupted at the well site during maintennce operations and discharged what appears to be less than 5 bbls of e&p waste (mist of crude oil and sw) to a wooded area behind the location.

so they had a verbal agreement to temporarily abandon the well set CIBP @ 14,800 feet dump 20-30' cmt on top run tubing hanger with 2 way check valve in wellbore close in manual and hydraulic 5 1/8" valves above wellhead  monitor well pressure

probably no big deal, but i don't know

Comment by David Crockett on February 9, 2020 at 14:00

Thanks RM. will be interesting to find out

 

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